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Home My WebLink About204-181 Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 06/01/2023 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 6/1/2023. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through 6/1/2023. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404 Report of Sundry Operations. If you have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Supervisor Hilcorp North Slope, LLC Hilcorp North Slope LLC.Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-offReport of Sundry Operations (10-404)06/01/2023Well NamePTD #API #Initial top of cement (ft)Vol. of cement pumped (gal)Final top of cement (ft)Cement top off date Corrosion inhibitor (gal)Corrosion inhibitor/ sealant dateL-2072210815002923702003.371.31/23/2023123/1/2023L-2312230105002923746003.003.0-393/27/2023M-111810575002920589002.602.6-105/29/2023M-311920325002922256001.501.5-165/29/2023M-331941165002922504001.301.3-145/29/2023N-171830095002920898001.201.2-115/30/2023N-18A2081755002920906010.500.5-65/30/2023N-21A1961965002921342011.001.0-85/30/2023N-272071045002923365000.500.5-45/30/2023N-292141105002923521002.302.3-245/30/2023N-31215175500292356000-0--205/30/2023V-2342220045002923707006.3210.91/23/2023243/1/2023W-2412221545002923741002.502.5-263/1/2023Z-121891025002921977000.700.7-45/23/2023Z-34212061500292346900-0--155/27/2023Z-402111735002923462000.700.7-65/27/2023Z-46A2052035002923280010.500.5-35/23/2023Z-502120015002923463000.500.5-35/27/2023Z-662121955002923482000.700.7-85/27/2023Z-116211124500292345500-0--175/27/2023Z-210204181500292322600-0--125/27/2023Z-2292221045002923726003.8361.23/5/2023363/27/2023-0--Z-210204181500292322600125/27/2023 Phu Z -2 to Winston, Hugh E (CED) ?TD ti ZoH - l8 From: Winston, Hugh E (CED) Sent: Tuesday, February 25, 2020 10:01 AM To: Rixse, Melvin G (CED); Roby, David S (CED); Davies, Stephen F (GED); Boyer, David L (CED) Subject: RE: 10-405/10-406 If there are no objections then I will go ahead and change both status's to "SI" as we wait for the reports for suspension and P&A'ing. Huey From: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Sent: Wednesday, February 19, 2020 11:17 AM To: Roby, David S (CED) <dave.roby@alaska.gov>; Davies, Stephen F (CED) <steve.davies@alaska.gov>; Boyer, David L (CED) <david.boyer2@alaska.gov>; Winston, Hugh E (CED) <hugh.winston@alaska.gov> Subject: RE: 10-405/10-406 I think Z-210 should be suspended and WETW should be P&A'd. Mel From: Roby, David S (CED) Sent: Wednesday, February 19, 2020 10:24 AM To: Davies, Stephen F (CED) <steve.daviesPalaska.eov>; Boyer, David L (CED) <david.boyer2@alaska.gov>; Rixse, Melvin G (CED) <melvin.rixse alaska.aov>; Winston, Hugh E (CED) <hueh.winston@alaska.aov> Subject: FW: 10-405/10-406 All, I think the two subject wells PBU Z-210 (PTD 204-181) and the WETW (PTD 183-157) should both have their statuses changed from WAGIN and 1-0I1- respectively to SI since they aren't physically connected into the PBU production/injection systems but aren't suspended. What do you think? Also, I think we should push for the WETW to be P&A'd since it is not on an active production pad and thus there's no future utility for the wellbore. Thoughts? Z-210 could probably be P&A'd, or at the very least suspended, as well. Thoughts? Thanks. Dave Roby 907-793-1232 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 a -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 Dave Roby at 907-793-1232 or dave.robv@alaska.zov. From: Roby, David S (CED) Sent: Wednesday, February 19, 2020 10:15 AM To: Ohms, Danielle H <Danielle.Ohms@bp.com> Cc: Benson, Gary <Gary.Benson@bp.com>; Bredar, William L <William.Bredar(@bp.com> Subject: RE: 10-405/10-406 Hi Danielle, After further consideration since neither well is physically connected to the production or injection infrastructure it is probably best to have their status changed to SI, which in our system is used for wells that don't qualify as suspended but would require significant facilities work to put them back into a condition where they could be put back into production/injection service. Wells with an SI status do not need to be reported on the 10-405/406 but do need to be addressed in the annual shut in wells report. I think we can make this change without the need for a 10-403/404, if I find out otherwise I'll let Bill know what we'll need. Congratulations on your retirement. Regards, Dave Roby 907-793-1232 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 Dave Roby at 907-793-1232 or dave.robv@alaska.eov. From: Ohms, Danielle H <Danielle.Ohms@bp.com> Sent: Wednesday, February 19, 2020 9:07 AM To: Roby, David S (CED) <dave.robv@alaska.gov> Cc: Benson, Gary A <Gary.Benson@bp.com>; Bredar, William L <William.Breda r@bp.com> Subject: RE: 10-405/10-406 Dave, Just checking back in on the path forward for WETW and Z-210. Gary plans to have both included on the January 10-405/10-406 report datafiles. I'll be retiring tomorrow so please communicate any follow-up needs with Bill Bredar. I've very much appreciated your helpfulness, knowledge and professionalism over the years of working with you on AOGCC regulatory matters. Thanks. Danielle Ohms AK PE Discipline Lead, FS2 Lead PE BP Exploration (Alaska) Inc. (907) 564-5759 office (907) 440-9082 cell ohmsdh(a)bp.com From: Ohms, Danielle H Sent: Wednesday, February 5, 2020 3:40 PM To: Roby, David S (CED) <dave.roby@alaska.eov> Cc: Benson, Gary A <Gary.Benson@bp.com>; Bredar, William L (William. Bredar@bp.com) <W illiam. Breda r(@ bp. com> Subject: RE: 10-405/10-406 Dave, To answer your questions below: 1. There are no current plans to drill a producer in the Z-210 area 2. Data in the OMAR database tables which since 1995 have been used to create the 10-405 and 10-406 reports goes back to January 1987. There are additional tables in OMAR which contain historical production and injection data going back to the 1970s. Gary has since reviewed the historical data tables and found the 1984 production data for WETW. He also discovered that the BP Well Status Code assigned to WETW in the master well table is "OS" (Operationally Suspended) which OMAR interprets to exclude the well from appearing on the 10-405 report. This code was probably assigned in 1994 in the transition from our previous production accounting system to OMAR. That would explain why the AOGCC database doesn't have any records for WETW beyond October 1994. He can change the BP Well Status Code in OMAR to "08" (Oil Producer Shut-in) so the WETW well will appear on the 10-405 reports again, beginning in January, if you do want it reported as such. 3. Correct — WETW is on its own, non -producing pad, and is not tied into production facilities. Please let us know how you'd like us to proceed with handling these 2 wells for 10-405 and 10-406 reporting purposes. Danielle Ohms AK PE Discipline Lead, FS2 Lead PE BP Exploration (Alaska) Inc. (907) 564-5759 office (907) 440-9082 cell ohmsdh(o)bp. com From: Roby, David S (CED) <dave.roby(aalaska.eov> Sent: Tuesday, February 4, 2020 2:42 PM To: Ohms, Danielle H <Danielle.Ohms@bp.com> Cc: Benson, Gary A <Garv.Benson(@bp.com>; Bredar, William L <William.Bredar(@bo.com> Subject: RE: 10-405/10-406 Danielle, A few questions. 1) According to the latest info in our file (see attached) for Z-210 there was a lack of oil in the fault block the well was completed in and no plans to drill any producers in the area. Is this still the case? 2) We have production records in our system for the WETW well from February 1984 through October 1994 (actual production only occurred February to July 1984). So it seems this well should be in your system, how far back do your production records go? 3) Looks like WETW well was drilled from its own gravel pad and is not on an actively producing pad nor tied into production facilities. Is this correct? Thanks, Dave Roby 907-793-1232 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 Dave Roby at 907-793-1232 or dave.robv@alaska.eov. From: Ohms, Danielle H <Danielle.Ohms@bo.com> Sent: Tuesday, February 4, 2020 2:09 PM To: Roby, David S (CED) <dave.roby@alaska.gov> Cc: Benson, Gary A <GarV.Benson@bp.Com>; Bredar, William L <William.Bredar@bp.com> Subject: 10-405/10-406 Dave, I'm following up from the conversation Gary Benson and I had with you on 1/23/20 regarding long term SI wells that were not on the 10-405/10-406 monthly reports. My understanding of our conversation was that the definition of "abandoned" wells that the form instructions indicate do not need to be reported, essentially includes suspended wells (wells plugged and/or perfs squeezed to prevent from flowing to surface -more than a TTP). While internally cross referencing our draft list of Long Term Shut in wells with wells reported on 10-405 and 10-406 Monthly reports, I found only 2 that were omitted but not formally AOGCC Suspended. These 2 wells are somewhat unique for reasons described below. Z-210: A Schrader (Orion) Appraisal well, listed as a Water Injector, though it has never been hooked up to Water Injection (nor production). There are currently no flowlines and the well is secured with a plug in the lower tubing. There is still a possibility of hooking this well up for Shrader injection in the future when/if there is Shrader offtake from Z Pad. We have no records of it ever being reported on a 10-406 Report as there was never any records of injection. WETW: West End Test Well, was production tested for a short period in 1984. It has no flowlines and is located on a pad extension off the road to W Pad. It is listed as an oil producer, however as far back as Gary is able to check OMAR records, it has had no period records and thus was not reported on the 10-405 Report. It is secured with a plug in the tubing tail. Because of the circumstances of these wells and challenges in our system with adding these wells to the reports while they have no period records, we'd like to ask that they continue to be excluded from the 10-405 and 10- 406 Reports. They will, however, continue to be included on the Annual Shut In Well Report. Please let us know how to proceed with handling these 2 wells for reporting purposes. Thanks. it • /f�J/rte AK PE Discipline Lead, FS2 Lead PE BP Exploration (Alaska) Inc. (907) 564-5759 office (907) 440-9082 cell ohmsdh p7bD.com 4Q2010 Not Operable Injector Re* • Page 1 of 2 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWellIntegrityCoordinator@bp.com] Sent: Friday, February 25, 2011 12:44 PM I 1 To: Maunder, Thomas E (DOA); AK, D &C Well Integrity Coordinator Subject: RE: 4Q2010 Not Operable Injector Report Tom, Z -210 has yet to be injected into. The well was drilled to support future producers, however, due to the lack of oil found in that fault block while drilling there were no plans to drill a producer. Z -19 - The well integrity team is waiting to hear back from the asset what the plan forward is. The AA will be cancelled if the asset does not have any near future utility for the well. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 201't Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Friday, February 25, 2011 12:26 PM To: AK, D &C Well Integrity Coordinator Subject: RE: 4Q2010 Not Operable Injector Report Gerry and Torin, I am reviewing the LTSI list and have some questions. It is likely that I will send several messages so as not to dump all the questions on you at one time. Here is the first go. So far I have looked up through WB -06 (5 wells). I look forward to your reply. Tom Maunder, PE AOGCC Z -210 204 -181 Our records does not show any injection having occurred into this well. Does your record confirm this? Can you provide a reason as to why the well has never been active? Z -19A 206 -105 If this well is to remain LTSI, should AA 3.017 amended be cancelled? From: AK, D &C Well Integrity Coordinator [mailto: AKDCWeIIIntegrityCoordinator @bp.com] Sent: Saturday, February 19, 2011 2:43 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA); Schwartz, Guy L (DOA) Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU 2/25/2011 4Q2010 Not Operable Injector Re, • Page 2 of 2 Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; AK, RES END Production Optimization Engineer; Kruger, Dale 0 Subject: 4Q2010 Not Operable Injector Report Hello Tom, Jim, Phoebe and Guy, Attached is the 4Q 2010 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors classified as Not Operable. «Not Operable Injector Report 4Q2010.zip» Notes on wells: Removed from Quarterly Injection Report: B1 -14: Passed AOGCC MITIA with Badami field restart R -13: Furmanite wrap repaired startinghead leak. Added to Quarterly Injection Report: MPF -92: Added until injection is requested. MPF -95: Added until injection is requested. MPL -09: Added until Furmanite clamp is fabricated and installed to mitigate startinghead leak. Z -12: Added until TxIA communication is repaired. Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 2/25/2011 Well Z -210 Injection Plot LTSI - no flowline Prpssurr vs Rate TIO Plot N O O CO — —Tbg IA OA CO o CD N m a N 2 a ov 0 0 N II ♦ Last 90 days • Last Month 0 0 0 1 1 1 1 6/18/10 9/8/10 11/29/10 2/19/11 Injection Rate, MCFPD 0 L\ ! V6 W w lL v'■ i '1 V. ) Volume Injected Tubing Pressure Tbg Press IA Press OA Press Date (BWPD / MCFPD) (psi) WHP Date (psi) (psi) (psi) k Cj �i 01/01/11 0 600 400 I > U ` 12/31/10 0 600 400 i 12/30/10 0 600 400 G vIt- G .‘ (\ 12/29/10 0 600 400 \ i 12/28/10 0 600 400 Y� ,\ C- `� i tC �� 12/27/10 0 600 400 12/26/10 0 600 400 (yy, /J 12/25/10 0 600 400 Ak "" J 12/24/10 0 600 400 ._ \ 12/23/10 0 600 400 (0 12/22/10 0 600 400 12/21/10 0 600 400 12/20/10 0 600 400 12/19/10 0 600 400 12/18/10 0 600 400 12/17/10 0 600 400 12/16/10 0 600 400 12/15/10 0 600 400 12/14/10 0 600 400 12/13/10 0 600 400 12/12/10 0 600 400 12/11/10 0 600 400 12/10/10 0 600 400 12/09/10 0 600 400 12/08/10 0 600 400 12/07/10 0 600 400 12/06/10 0 600 400 12/05/10 0 600 400 12/04/10 0 600 400 12/03/10 0 600 400 12/02/10 0 600 400 ) ~ N'N ,l~~ y. DATA SUBMITTAL COMPLIANCE REPORT 10/13/2006 Permit to Drill 2041810 MD 5958 Well Name/No. PRUDHOE BAY UN ORIN Z-210 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23226-00-00 TVD 5118 Completion Date 10/31/2004 Completion Status WAGIN Current Status WAG IN UIC Y REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Interval . OHI Start Stop CH Received Comments 4500 6700 Case 11/23/2004 ULTRASONIC IMAGING I TOOU7.0", 26# CEMENTY I CORROSION MODE 4500 6700 Case 11/23/2004 ULTRASONIC IMAGING TOOL/7.0", 26# CEMENTY CORROSION MODE IDSN11790 3925 6858 Open 11/15/2004 IIFR 3925 6858 Open 11/15/2004 IIFR 3925 6858 Open 11/15/2004 MWD 3925 6858 Open 11/15/2004 MWD 0 7900 Open 11/15/2004 IIFR PB1 0 7900 Open 11/15/2004 IIFR PB1 0 7900 Open 11/15/2004 MWD PB1 . 0 7900 Open 11/15/2004 MWD PB1 543 6931 Open 3/1612005 GR/EWR4/CNP/SLD/ROPI ACAL/PWD/MWD 543 6931 Open 3/16/2005 GR/EWR4/CNP/SLD/ROPI ACAUPWD/MWD 543 7867 Open 3/16/2005 GR/EWR4/CNP/SLJ~OPI I ACAUPWD/MWD f 543 7867 Open 3/16/2005 GRlEWR4/CNP/Sp/ROPI ACAL/PWD/MWD 6 I 0 0 5/26/2005 Black Oil PVT Study Report-PB1 --~-----' DATA INFORMATION Types Electric or Other Logs Run: MWD 1 GR, MWD 1 GR 1 RES 1 DEN 1 NEU 1 PWD, MDT, MWD 1 GR 1 Well Log Information: Logl Data Digital C Mw/F~t . C Pds Lo D Asc D Asc D Asc D Asc D Lis D Lis I L Electr Dataset Number Name 11790 Cement Evaluation Log Log Scale Media Run No 1 11790 Cement Evaluation Col Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey 13086 InductionlResistivity 13086 LIS Verification 13087 InductionlResistivity 13087 LIS Verification See Notes DATA SUBMITTAL COMPLIANCE REPORT 10/13/2006 Permit to Drill 2041810 Well Name/No. PRUDHOE BAY UN ORIN Z-210 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23226-00-00 ~. 5958 J'ED C Lis Completion Status UIC Y ROP DGR EWR SLD CTN1 plus Graphics 1 PB 1 109- I 7900 ROP DGR EWR SLD I CTN plus Graphics J WAGIN Current Status WAGIN 6958 Open 2/22/2006 TVD 5118 Completion Date 10/31/2004 13726 Induction/Resistivity 109 -~_. Well Cores/Samples Information: Name Interval Start Stop Sample Set Number Comments Sent Received ADDITIONAL INFORMATION Well Cored? Y 1 N Daily History Received? Y/N fi)N Chips Received? Y / N Formation Tops Analysis Y / N Received? Comments: ~ Date: l' Mtv L~ Þ Compliance Reviewed By: . . . . WELL LOG TRANSMITTAL L)¡Û d-D4---- I 8 I To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 17, 2006 rò1~(P RE: MWD Formation Evaluation Logs 2-210 + PB1, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 Z-210 + PBl: LAS Data & Digital Log Images: 50-029-23226-00, 70 1 CD Rom Q®J ~I~ . . ¿¿01-ffr WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Wannan 333 West ih Avenue, Suite 100 Anchorage, Alaska February 22, 2005 RE: MWD Fonnation Evaluation Logs 2-210, AK-MW-3328880 1 LDWG fonnatted Disc with verification listing. API#: 50-029-23226-00 \ '/ lV' .". , -i>" (7 6Ò 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) mc. Petro- Technical Data Center LR2-l 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: f~~ .![~<- . . c:2 () c/_ ) ìf J WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West ih Avenue, Suite 100 Anchorage, Alaska February 22, 2005 RE: MWD Formation Evaluation Logs 2-210 PBl, AK-MW-3328880 I LDWG formatted Disc with verification listing. API#: 50-029-23226-70 \7~l ~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: J ¡,., (0 í ~ .. STATE OF ALASKA _ ALAS~ AND GAS CONSERVATION COM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: D Oil DGas D Plugged D Abandoned D Suspended a WAG 1b. Well Class: 20AAC 25.105 20AAC 25.110 D Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions One Other D Stratigraphic a Service 2. Operator Name: 5. Date Camp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 10/31/2004 204-181 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 10/10/2004 50- 029-23226-00-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 10/25/2004 Z-210i 4565' NSL, 3578' WEL, SEC. 19, T11N, R12E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 4726' NSL, 144' EWL, SEC. 20, T11N, R12E, UM 81.9' Prudhoe Bay Field I Orion Schrader Bluff Total Depth: 9. Plug Back Depth (MD+ TVD) 4611' NSL, 453' EWL, SEC. 20, T11 N, R12E, UM 6867 + 5040 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 599095 y- 5959360 Zone- ASP4 6958 + 5118 Ft ADL 028262 TPI: x- 602814 y- 5959571 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 603125 y- 5959460 Zone- ASP4 (Nipple) 3237' MD 18. Directional Survey 19. Water depth, if offshore 20. Thickness of Permafrost aYes DNa NIA MSL 1900' (Approx.) 21. Logs Run: MWD I GR, MWD I GR I RES I DEN I NEU I PWD, MDT, MWD I GR I RES I DEN I NEU I PWD, USIT 2. (;ASING, LINER AND (;EMENTING RECORD ~~~4~G .... ~I'TTI",c¡ Ea>TIi. MP ;:)E'J'TINGI )Ep-rH'TVO ~~: .'. Xi Wr;PERFT. G~P~. "BOTTOM I BOTTOM <"" Co". >PII;It="\ lOP lOP > 20" 166.4# X-56 Surface 109' Surface 109' Driven 260 sx Arctic Set (Approx) 9-5/8" 40# K-55 I L-80 24' 3811' 24' 2830' 12-1/4" 584 sx AS Lite, 379 sx Class 'G' 7" 26# L-80 26' 6949' 26' 5110' 8-3/4" 313 sx Class 'G', 23. Perforations open to Production (MD + TVD of Top and 24: il ....' , .." Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Gun Diameter, 5 spf 4-1/2", 12.6#, L-80 6313 MD TVD MD TVD 3-1/2", 9.3#, L-80 6313' - 6640' 6324',6419',6524',6590' 6366' - 6400' 4627' - 4653' 25.. ACID,'" "" 6446' - 6480' 4688' - 4715' , ,,,..,, '"!,",,,,,\JEMENT -'. < 6486' - 6500' 4719' - 4731' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6548' - 6576' 4769' - 4792' 6618' - 6654' 4827' - 4857' 2774' Freeze Protect wI 95 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Injection Yet NIA Date of Test Hours Tested PRODUCTION FOR Oll-Bsl GAs-McF WATER-BSl CHOKE SIZE GAS-Oil RATIO TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ... O'l-Bsl GAs-McF W A TER-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-r.;;:;~;;--;:,"'":";::';"\ RBDMS BFL DEC 0 'J' ?nnð None j ;~~~¡~ ORIGINAL 1~0!' , ..- I ,., .":--. í u.. .", .;_......."'~...-.....--"._......~-'..,~ Form 1 0-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKER 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 MB1 Ugnu MB2 Ugnu MC 4195' 5795' 5859' 5929' 6000' 3065' 4211' 4257' 4308' 4359' MDT was ran, log supplied for detail. Schrader Bluff NA 6109' 4439' Schrader Bluff NB 6149' 4468' Schrader Bluff NC 6212' 4514' Schrader Bluff OA 6364' 4626' Schrader Bluff OBa 6443' 4686' Schrader Bluff OBb 6481' 4716' Schrader Bluff OBc 6545' 4767' Schrader Bluff OBd 6613' 4823' Schrader Bluff OBe 6680' 4879' Schrader Bluff OBf 6728' 4920' Base Schrader Bluff OBf 6788' 4972' 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 11- 30-D 2-210; Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Rob Tirpack, 564-4166 204-181 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 Z-210 PBl State MDT Results (2).XLS Well: Z-210PB1 Date: 10/17/2004 I 1 6460 4314 2214 2202 12.0 1936 78.9 Temp: 90.16° Good test P Mb-1 2 6575 4380 2257 2246 11.0 1988 12.6 Temp: 92.7° Lost seal, reset, G test P Mb-z 3 6655 4427 2280 2272.0 8.0 1198 44.2 Temp: 93.3° Good test P Me 4 7124 4703 2424 2414.0 10.0 2084 9.6 Temp: 96.1° Good test P OA 5 7128 4705 2420 2410.0 10.0 2084 11.6 Temp: 96.4° Good test P OA 6 7149 4717 2430 2416.0 14.0 2113 1.6 Temp: 96.7° Good test P OA 7 7233 4766 2457 2443.0 14.0 Temp: 97.3 Tight, supercharged P Upper OBa 8 7234 4767 2448 2438.0 10.0 2119 3.0 Temp: 97.6° P Upper OBa 9 7239 4770 2452 2438.0 14.0 2121 2,8 Temp: 97.5° Good test P Upper OBa 10 7260 4782 2478 2450.0 28.0 2102 43.5 Temp: 97.9° Good test P Lower OBa 11 7262 4783 2460 2448.0 12.0 2102 39.3 Temp: 98.0° Good test P Lower OBa 12 7286 4796 2466 2451.0 15,0 2311 1,3 Temp: 98.0° Good test P OBb 13 7292 4800 2471 2451.0 20.0 2461 0.0 Temp: 97.8° tight, supercharged P OBb 14 7304 4807 2473 2457.0 16.0 2148 3.6 Temp: 98.0° Good test P OBb 15 7380 4850 2510 2492.0 18.0 2132 29.2 Temp: 98.1° Good test P OBc 16 7385 4852 2489 2480.0 9.0 2134 12.4 Temp: 98.3° Good test P OBc 17 7405 4864 2502 2490.0 12.0 2137 193,9 Temp: 98.4° Good test P OBc 18 7483 4908 2523 2513.0 10.0 2152 20.9 Temp: 98.5° Good test P OBd 19 7493 4914 2526 2515.0 11.0 2156 27.0 Temp: 99.1° Good test P OBd 20 7524 4931 2541 2526.0 15.0 2161 7.7 Temp: 99.4° Good test P OBd 21 7564 4954 2558 2549.0 9.0 Temp 99" Dry test P OBd 22 7566 4955 2544 2537.0 7.0 Temp 99" Dry test P OBd 23 7563 4954 2530 2530.0 0.0 Temp 100° Dry test P OBd 24 7493 4914 2478 1300 Good 1 gal. Sample F OBd 25 7139 4705 2347 1000 Good 1 gal. Sample F OA 26 7263 4783 2423 1500 Good 450 ml sample F Lower OBa 27 7235 4767 2373 No flow Upper OBa 28 7405 4864 2454 1500 Good 450 ml sample F OBc 29 7304 4807 2401 No flow OBb 30 6460 4314 2149 No flow Ugnu Mb1 . . Page 1 ,678 (psi) 11 .42 (ppg) - Printed: 11/1/2004 1:50:00 PM 355 (psi 9.00 (ppg) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-21 0 Z-210 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 10/8/2004 1 0/31 /2004 Spud Date: 10/10/2004 End: 10/31/2004 10/5/2004 14:00 - 17:30 3.50 MOB P PRE Prepare for Move: Disconnect mud lines at Pit / sub interconnect. Remeove kelly hose from Top Drive. Disconnect 4" standpipe. Remove 2" standpipe. Install jeep on pits. Remove blocks from Top Drive & Bridle up. Grease bridle line sheaves. 17:30 - 00:00 6.50 MOB P PRE Wait on Rig move equipment - Sows, Cats & trucks working on 4 ES move to W Pad. Perform rig maintenance and cleaning while waiting. 1 0/6/2004 00:00 - 09:30 9.50 MOB P PRE Continue to wait on moving equipment ( 4 ES Move to W Pad) 09:30 - 10:30 1.00 MOB P PRE Blow down pits, disconnect electric lines from shop, camp & pits. 10:30 - 12:00 1.50 MOB P PRE PJSM with Tool Pusher, Peak Pusher & Drivers + Rig Crew. Move shop, camp & pits to DS-12 entrance. 12:00 - 13:00 1.00 MOB P PRE Wait on Security for move. 13:00 - 23:00 10.00 MOB P PRE Move shop, camp and pits down Spine Rd. On DS-12: lower cattle chute, Lower Derrick & jack up sub. Move sub to entrance to DS-12 @ 20:30 Hrs. Camp, shop & pits on Z-Pad @ 23:00 Hrs. 23:00 - 00:00 1.00 MOB P PRE With Security, Move Sub-Base off DS-12 to East Checkpoint. 10/7/2004 00:00 - 04:00 4.00 MOB P PRE Continue moving sub-base past East check point to next intersection, when making corner rear tires got to close to the shoulder of the road causing road to give way. Field engineer Scott Grieve was notifyed 04:00 - 20:00 16.00 MOB P PRE Blocked up under tires, during this operation rig slid approximately 2' in the wrong direction, due to the slippery road conditions, hooked 4 Peak Cats to hold rig from sliding and assist back on road. 20:00 - 00:00 4.00 MOB P PRE Continued moving sub-base on west dock road between the Lisburne and Oxbow road. Hydraulic hose failed on the rig moving system. 1 0/8/2004 00:00 - 02:30 2.50 MOB P PRE Repair hydraulic line on moving system. 02:30 - 03:00 0.50 MOB P PRE Continue moving sub-base, moved approximately 500', over heat alarm on moving system hydraulics going off. 03:00 - 06:00 3.00 MOB P PRE Called mechanic & electrician and repair problem. 06:00 - 00:00 18.00 MOB P PRE Continue Moving sub-base along West dock road, to K-pad road. Right on Spine road to R-pad turn off at midnight. 10/9/2004 00:00 - 09:30 9.50 MOB P PRE Move Sub-base from R-pad access road across Kaparuk bridges on to Z-pad access road. Turning onto Z-pad access road at 0:700 Hrs. Rig on location at 09:30 hrs. 09:30 - 12:00 2.50 MOB P PRE Lay mats and herculite for sub, posiotion sub to pull on well. 12:00 - 17:30 5.50 MOB P PRE Spot Camp and truck shop. Set 20" annular and well head equipment in cellar, Spot and level sub on Z-210 , spot pits and cuttings tank. Hook up service lines 17:30 - 19:00 1.50 RIGU P PRE PJSM, Inspect and raise derrick, raise pipe chute. 19:00 - 22:00 3.00 RIGU P PRE Unbridle and hang back bridle lines, P/U topdrive, hook up mud line, cement line and topdrive hose, rig up floor. 22:00 - 00:00 2.00 RIGU P PRE Nipple up 20" annular and diverter line, take on spud mud, and load pipe shed with 120 jts. 4" DP, 18 jts 4" HW and BHA. Accept Rig at 22:00 hrs. 10/9/2004 10/10/2004 00:00 - 04:00 4.00 RIGU P PRE Held Pre-spud meeting with Co. Rep, Toolpusher and rig crew. Continue Nipple up 20" diverter and riser. Change out air boot on riser. Printed: 11/1/2004 1 :50:06 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-210 Z-210 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 1 0/8/2004 1 0/31 /2004 Spud Date: 10/10/2004 End: 10/31/2004 P/U 120 jts 4" Dp, 18 jts 4" HWDP and stand back. Function test Diverter. John Crisp with AOGCC waived witness of diverter test. 09:00 - 10:00 1.00 RIGU P PRE Hook up topdrive blower hose, rig up Sperry-Sun E-line unit and gyro tools. 10:00 - 11 :00 1.00 RIGU P PRE M/U 12.25" Hughes MX-C1 bit and 8" motor, orient UBHO sub. 11 :00 - 11 :30 0.50 RIGU P PRE Fill riser and check for leaks, test surface equipment to 3,500 psi. 11 :30 - 12:00 0.50 DRILL P SURF Tag up at 70' clean out conductor from 70' to 109', up wt = 40k, dn wt = 40k, rt wt = 40k, 430 gpm @ 400 psi, torque = 500 ft/lbs. 12:00 - 17:00 5.00 DRILL P SURF Drill 12.25" surface hole from 109' utilizing Gyro-date surface read out gyro, began kickoff at 254' drilled to 583' 10-15 wOb, 440 gpm, 800 psi, 60 rpm, torque 2k, up wt = 58k, dn wt = 58k, rt wt = 58k, ART = 1.08 AST = .75 17:00 - 17:30 0.50 DRILL P SURF POH to pick up remaining BHA. 17:30 - 20:00 2.50 DRILL P SURF Pickup MWD, orient and test MWD, Pickup flex collars, and RIH to 583', no fill 20:00 - 20:30 0.50 DRILL P SURF Gyro at 553' 20:30 - 00:00 3.50 DRILL P SURF Drill from 583' to 833', 15-20k wob 450 gpm, 1,500 psi on bottom, 1,370 psi off bottom, 60 rpm, torque 3k on bottom, 1.5k off bottom. up wt = 68k dn wt = 68k, rt wt = 68k. ART = .67 AST = .88 10/11/2004 00:00 - 08:30 8.50 DRILL P SURF Directional drill 12.25" hole from 833' to 1 ,606', 15-20k wob 450 gpm, 1,580 psi on bottom, 1,425 psi off bottom, 60 rpm, torque 4.5k on bottom, 2.5k off bottom. up wt = 70k dn wt = 68k, rt wt = 68k. Ran a total of 8 gyro surveys. At 1,606' Directional driller was concerned with an anit-collision issue, decision was made to make 5 std short trip. 08:30 - 09:30 1.00 DRILL P SURF Back ream out from 1,606' to 1,024', with 450 gpm, 1420 psi, 60 rpm, torque 3-4k. while evaluating survey data. After further evaluation it was Determined anti- collision could be avoided with the current BHA. 09:30 - 10:00 0.50 DRILL P SURF RIH to 1,599' fill pipe and orient high side, wash to bottom, no fill. 10:00 - 12:00 2.00 DRILL P SURF Directional drill 12.25" hole from 1,606" to 1,790', 15-20k wob 450 gpm, 1,580 psi on bottom, 1,425 psi off bottom, 60 rpm, torque 4.5k on bottom, 2.5k off bottom. up wt = 85k, dn wt = 65k, rt wt = 73k. ART = 1.69 AST = 6.37 12:00 - 16:00 4.00 DRILL P SURF Directional drill 12.25" hole from 1,790" to 2,172', 15-20k wob 450 gpm, 1,580 psi on bottom, 1,425 psi off bottom, 60 rpm, torque 4.5k on bottom, 2.5k off bottom. up wt = 85k, dn wt = 65k, rt wt = 73k. ART = 2.41 AST = 1.94 16:00 - 16:30 0.50 DRILL P SURF Circulate hole clean, 450 gpm @ 1,450 psi. Rotating string at 80 rpm on up stroke, orient motor to high side and wash down on down stroke. 16:30 - 19:00 2.50 DRILL P SURF Monitor well, POH for bit change. No problem on trip out. 19:00 - 20:30 1.50 DRILL P SURF Change bit and adjust motor to 1.5 deg, UD UBHO sub, Printed: 11/1/2004 1 :50:06 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-210 Z-210 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 10/8/2004 10/31/2004 Spud Date: 10/10/2004 End: 10/31/2004 10/11/2004 19:00 - 20:30 1.50 DRILL P SURF change out pulser, orient MWD and motor, surface test MWD. 20:30 - 21 :00 0.50 DRILL P SURF Service rig & topdrive 21 :00 - 23:00 2.00 DRILL P SURF RIH, taking check shots to satisfy JORPs @ 1,276' - 1,339' 1-1,791' - 1,859' - 1,890' - 1,952' these areas had doglegs in I excess of 5/100. Took weight at 1,805', made up topdrive and I washed from 1,800' to 1,855', RIH with no problems> Made up topdrive and washed last stand to bottom as a precaution. 23:00 - 00:00 1.00 DRILL P SURF Directional drill 12.25" hole from 2,172' to 2,361', 25-35k wob 550 gpm, 2,550 psi on bottom, 2,375 psi off bottom, 80 rpm, torque 6.5k on bottom, 4.5k off bottom. up wt = 90k, dn wt = 55k, rt wt '" 75k. started the 4/100 planned turn at 2,265'. ART = .38 AST = .08 10/12/2004 00:00 - 08:45 8.75 DRILL P SURF I Directional drill 12.25" hole from 2,361' to 3,832' with 25-35k wob, 550 gpm, 2500 psi on bottom, 2375 psi off bottom, 80 rpm, 6.5k torque on bottom, 4.5k off bottom. Encountered hydrates at 2,670',2,840'-.3,151'- 3,832', Added 4 drums Lecithin. ART = 3.8 AST = 2.28 08:45 - 10:00 1.25 DRILL P SURF Circulate bottoms up 21/2 times, 650 gpm, 3120 psi, rotating string 100 rpm, torque 4.5k, reciprocate full stand. 10:00 - 13:00 3.00 DRILL P SURF Monitor well, well not flowing, POH from 3,832' pulled tight at 3,413' 50k over, made up topdríve and back ream from 3,413' to 1,692" 600 gpm, 2,330 psi, 60 rpm, torque 4-5k. pulled 20k over through high doglegs at 1,805 ream this section several times. 13:00 - 14:30 1.50 DRILL P SURF Monitor well, RIH took weight at 3,405' worked through this area without pumping, RIH to 3,700' wash from 3,700' to 3,832' as a precaution. 14:30 - 16:30 2.00 DRILL P SURF Circulate bottoms up 21/2 times, at 650 gpm, 3090 psi, 100 rpm, torque 4-5k, reciprocate pipe full stand. 16:30 - 19:00 2.50 DRILL P SURF Monitor well and POH to BHA. 19:00 - 20:30 1.50 DRILL P SURF Lay down BHA, down load MWD in pipe shed. 20:30 - 21 :00 0.50 DRILL P SURF Clear and clean floor. 21 :00 - 22:30 1.50 CASE P SURF Rig up casing tools, Make up casing fill up tool, make dummy run with casing hanger and landing joint. 22:30 - 23:00 0.50 CASE P SURF PJSM, Run Surface casing 23:00 - 00:00 1.00 CASE P SURF Run 95/8" 40# K-55 & L-80 casing per running order. 1 0/13/2004 00:00 - 04:00 4.00 CASE P SURF Run 95/8" 40# K-55 & L-80 casing, ran a total of 91 jts, 85 jts 40# K-55, 6 jts, 40# L-80, picked up hanger and landing joint. Engauge Franks tool, break circulation and wash last joint to bottom. 04:00 - 04:45 0.75 CEMT P SURF Stage up pumps to 10 bpm @ 660 psi, circulate 1 complete circulation with Franks tool, reciprocating string 20', cut vis back to 70-80 and reduce YP to 15-20. Up weight = 195k, down weight = 100k. 04:45 - 05:30 0.75 CEMT P SURF Lay down Franks tool, blow down topdrive, make up cement head. 05:30 - 06:00 0.50 CEMT P SURF Circulate and condition mud @ 10 bpm, 750 psi. 06:00 - 06:30 0.50 CEMT P SURF Wash out on stand pipe, hook up secondary kill line to bypass wash out. 06:30 - 08:30 2.00 CEMT P SURF Circulate and condition mud @ 10 bpm, 750 psi. held PJSM with Co Rep, Toolpusher, cementers and rig crew while circulating. Repair wash out. Printed: 11/1/2004 1 :50:06 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-210 2-210 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 1 0/8/2004 1 0/31 /2004 Spud Date: 10/10/2004 End: 10/31/2004 10/13/2004 08:30 - 11 :45 3.25 CEMT P SURF Pump 5 bbls. water. Pressure test lines to 3,500. Pump 75 bbl mudpush weighted to (10.0 ppg) and kick out bottom plug. Reciprocating string 20' srtokes, pump 463 bbls.(584 sks.) (yield 4.44 cu.ftlsk) of 10.7 ppg. ArcticSet Lite" lead at 8-9 bpm, with 433 bbls of lead pumped, developed a wash out in the cement line, rigged up lines to bypass wash out. Continue pumping the 30 bbls of lead, reciprocating pipe 10' strokes, worked srting up the second time took weight unable to land casing on ring, 5.5' off ring. Pump 79 bbls. (378 sks.) (yield 1.17 cu.ftIsk) Class 'G' tail @ 15.8 ppg. at 5 bpm. Kick out Top plug with 10 bbls water from Dowell to clear lines then switch to Rig Pumps and displace cement @ 10 BPM.Slowed rate to 2 BPM and bumped plug at calculated displacement. pressure up to 1800 psi. CI P @ 11 :45 50 bbls good cement to surface. 11:45 - 12:00 0.25 CEMT P SURF Bled pressure off and checked floats, prepare to flush riser. 12:00 - 14:30 2.50 CEMT P SURF Flush riser and flow line, blow down cement and mud lines, rig down cementing equipment. 14:30 - 16:30 2.00 BOPSU SURF Nipple down diverter line, Pickup casing string to 230k, pickup 20" annular and install emergency slips. Cut off 9 5/8" casing and lay down landing joint. 16:30 - 17:30 1.00 BOPSU P SURF Wash out 20" annular, knife valve, riser and set back. 17:30 - 21 :00 3.50 BOPSU P SURF Made final cut on 9 5/8" casing and prep cut, install FMC adapter nipple, pre heat with Hot-Head to 450-650 deg. Weld on adapter nipple and post heat with Hot-Head, wrap with insulation. 21 :00 - 00:00 3.00 BOPSU N STUC SURF Wait on FMC adapter head to cool down slowly. Load pipe shed with 129 jts. 4" DP 6 jts. 4" HWDP and 3 flex collars, Pickup DP and rack in derrick. 10/14/2004 00:00 - 06:30 6.50 WHSUR N STUC SURF P/U 129 jts 4" DP 6jts 4" HWDP, NM flex collars, while waiting for FMC weld on adapter nipple to cool. 06:30 - 07:30 1.00 WHSUR N STUC SURF Service Ríg and topdrive. 07:30 - 11 :30 4.00 WHSUR N STUC SURF Wait on FMC adapter nipple to cool down, perform general maintenance. 11 :30 - 12:00 0.50 WHSUR N STUC SURF Rig up and test FMC adapter nipple with nitrogen, discovered leak on inside weld. 12:00 - 14:30 2.50 WHSUR N STUC SURF Re-weld inside of adapter nipple, post heat with Hot-Head, wrap with insulation. 14:30·00:00 9.50 WHSUR N STUC SURF Wait on FMC adapter nipple to cool down, Change oil in topdrive, drawworks, inspect chains in drawworks, inspect gear end lube pump on #2 mud pump, load pipe shed with 4.5" completion string. 10/15/2004 00:00 - 01 :00 1.00 WHSUR N STUC SURF Pull insulation off adapter nipple, and allow to cool. 01 :00 - 01 :30 0.50 WHSUR N STUC SURF Rig up and test welds on adapter nipple with nitrigen to 1,650 psi, good test. 01 :30 - 03:00 1.50 WHSUR P SURF Nipple up FMC Gen V casingl tubing head and test M/M seal to 1000 psi. 03:00 - 04:00 1.00 WHSUR P SURF Nipple up BOP and drilling nipple 04:00 - 09:00 5.00 WHSUR P SURF Rig up BOP test equipment, and test BOP to 250 psi low, 4000 psi high per Nabors test procedure. Jeff Jones with AOGCC waived witness of BOP test. 09:00 - 10:00 1.00 WHSUR P SURF Rig down test equipment, blow down choke manifold, install wear ring. 10:00 - 12:00 2.00 DRILL P PROD1 Pickup BHA as-per Sperry - Sun Directional driller. Printed: 11/1/2004 1:50:06 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-210 Z-210 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 10/8/2004 10/31/2004 Spud Date: 10/10/2004 End: 10/31/2004 10/15/2004 12:00 - 12:30 0.50 DRILL P PROD1 PJSM, with Sperry-Sun, load Nuke sources. 12:30 - 14:00 1.50 DRILL P PROD1 RIH to 3,613' make up topdrive and wash from 3,613' to 3,709' 14:00 - 14:30 0.50 DRILL P PROD1 Circulate bottoms up at 500 gpm, 1740 psi. 14:30 - 16:00 1.50 WHSUR P PROD1 Blow down topdrive, rig up and test 9 5/8" casing to 3000 psi for 30 min. record on chart. 16:00 - 16:45 0.75 DRILL P PROD1 Drill cement and float equipment from 3,709' to 3,812' drill 20' of new hole to 3,852', 5k wob, 50 rpm, 500 gpm at 1900 psi. 16:45 - 17:30 0.75 DRILL P PROD1 Displace hole to 9.0 ppg LSND mud. @ 500 gpm, 1870 psi, 80 rpm, torque 4k. 17:30 - 18:00 0.50 DRILL P PROD1 Rig up and perform FIT, 3,811' md, 2,829' tvd. 9.0 ppg, pressure attained 355 psi. EMW = 11.4 ppg. Rig down testing equipment, Make up topdrive, establish base line ECD at 575 gpm, 80 rpm, clean hole ECD = 9.8 ppg 18:00 - 00:00 6.00 DRILL P PROD1 Directional drill 8.75" hole from 3,852' to 4,951', with 10-15k wob, 580 gpm, 2390 psi on bottom, 2260 psi off bottom, 80 rpm, torque on bottom 7k, torque off bottom 5.5k. up wt = 125k, dn wt = 80k, str wt = 98k.Pumped two 50 bbl high vis sweeps @ 4,377' - 4,769' , 50% increase in cuttings with both sweeps. ECD 10.0 to 10.2, AST = .61 ART = 1.99 10/16/2004 00:00 - 12:00 12.00 DRILL P PROD1 Directional drill 8.75" hole from 4,951' to 6,768', with 10-15k I wob, 580 gpm, 3050 psi on bottom, 2920 psi off bottom, 80 rpm, torque on bottom 7-8k, torque off bottom 5-6k. Up wt = 130k, dn wt = 85k, rt wt = 105k. Pumped two 50 bbl high vis sweeps, at 5,908' - 6,672' both brought back a significant amount of cuttings. ART = 3.9 AST = 2.32 12:00 - 22:00 10.00 DRILL P PROD1 Directional drill 8.75" hole from 6,768" to TD at 7,900', with 10-15k wob, 580 gpm, 3410 psi on bottom, 3200 psi off bottom, 80 rpm, torque on bottom 9k, torque off bottom 6.5k. Up wt = 150k, dn wt = 100k, rt wt = 120k. Pumped two 50 bbl sweeps one high vis, one weighted high vis, 7,055' - 7,900', both brought back 50% more cuttings. Control drill from 7,100' to 7,900' at 180 fph, for log quality ART = 5.78 AST = 1.25 22:00 - 00:00 2.00 DRILL P PROD1 Pump 50 bbl high vis sweep, circulate bottoms up 2 1/2 times at 580 gpm 3,130 psi, rotating string 100 rpm, torque 6.5k, reciprocating pipe full stand. Sweep brought back a minimal amount of cuttings. 10/17/2004 00:00 - 00:30 0.50 DRILL P PROD1 Monitor well, POH from 7,900' to 7,350', no problems. 00:30 - 04:00 3.50 DRILL P PROD1 MAD pass from 7,350' to 6,850' at 180 fph, 580 gpm, 3030 psi, rotating string 50 rpm, torque 6.5k 04:00 - 06:30 2.50 DRILL P PROD1 Pump dry job and POH from 6,850' to 3,809' monitor well. 06:30 - 07:00 0.50 DRILL P PROD1 Service rig and topdrive. 07:00 - 09:00 2.00 DRILL P PROD1 RIH from 3,809' to 7,900', no problems. 09:00 - 10:30 1.50 DRILL P PROD1 Stage up pumps to 580 gpm, 3,100 psi and 100 rpms, torque 6.5k, pump 50 bbl high vis sweep, bottoms up saw a 50 % increase in cuttings. 10:30 - 12:00 1.50 DRILL P PROD1 Monitor well, pump dry job and POH from 7,900' to 5,981', drop drift. 12:00 - 15:00 3.00 DRILL P PROD1 POH from 5,981' to BHA, monitor well. 15:00 - 18:30 3.50 DRILL P PROD1 Stand back 4" HWDP, flush BHA with water, blow down topdrive, held PJSM, remove nuke sources, down load MWD, break bit and stand back motor and MWD. Printed: 11/1/2004 1 :50:06 PM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-210 Z-210 DRlll+COMPlETE NABORS ALASKA DRilLING I NABORS YES Start: Rig Release: Rig Number: 10/8/2004 1 0/31 /2004 Spud Date: 10/10/2004 End: 10/31/2004 1 0/22/2004 17:00 - 17:30 0.50 PXA P ABAN Clean floor and rig up 3.5" tubing handling equipment and power tongs. 17:30 - 19:45 2.25 PXA P ASAN Pickup 3.5" cement string as follows, 3.5" ported plug catcher and 40 joints of 3.5" 9.2# L-80 NSCT tubing. 19:45 - 20:00 0.25 PXA P ASAN Rig down 3.5" tubing equipment and power tongs. 20:00 - 23:00 3.00 PXA P ASAN RIH with cement string on 4" DP to 7,900', pickup to 7,890'. 23:00 - 00:00 1.00 PXA P ABAN Circulate bottoms up @ 420 gpm, 1,700 psi. reciprocating srting 30'. Chuck Scheeve with AOGCC waived witness of setting P&A cement plugs. Vehicle accident see IR# 1098877 10/23/2004 00:00 - 00: 15 0.25 PXA P ASAN Held PJSM with Co Rep, Toolpusher, Veco drivers, Schlumberger, while circulating. 00:15 - 01:15 1.00 PXA P ABAN Pump 5 bbls water and test lins to 3,500 psi, pumped 15 bbls water, pump 87 bbls 15.8 ppg class G cement, at 3 bpm, at 350 psi, pump 3.4 bbls water behind and displace cement with rig pumps at 10 bpm, 1820 psi pumped calculated strokes to balance plug. Plug in place at 01 :15 hrs 01:15 - 02:00 0.75 PXA P ABAN Lay down circulating head and POH to 6,996' 02:00 - 03:00 1.00 PXA P ASAN Circulate bottoms up at 420 gpm, 1600 psi, started seeing cement contaminated mud, 48 bbls prior to bottoms up dumped a total of 130 bbls, no evidence of good cement to surface. 03:00 - 04:00 1.00 PXA P ASAN Pumped 20 bbls water ahead, pump 87 bbls 15.8 ppg class G cement, at 3 bpm, at 330 psi, pump 3.4 bbls water behind and displace cement with rig pumps at 10 bpm, 1980 psi pumped calculated strokes to balance plug. Reciprocated pipe 20' during cement job. Up WI = 150k dn WI = 82k. Cement plug in place at 03:50 hrs. 04:00 - 05:00 1.00 PXA P ASAN Lay down circulating head, and POH to 6,007' 05:00 - 07:30 2.50 PXA P ABAN Drop DP wiper dart circulate bottoms up at 550 gpm, 1,640 psi, contaminated mud to suface, 40 bbls from calculated bottoms up dumped 115 bbls, of cement contaminated mud, no evidence of good cement to surface. Continued conditioning mud. 07:30 - 09:30 2.00 PXA P ASAN Monitor well, POH 09:30 - 11 :00 1.50 PXA P ABAN Change over to 3.5" Handling equipment, Rig up tubing power tongs, lay down 40 jts 3.5" tubing and perforated plug catcher. 11 :00 - 12:00 1.00 PXA P ASAN Rig down tubing handling equipment and clean floor. 12:00 - 15:00 3.00 PXA N RREP ASAN Repair chain on Draw works. 15:00 - 19:15 4.25 DRILL P PROD1 Pickup BHA as per Sperry - Sun, (had to steam out MWD tools, ports and sensors, tools were left racked back in the derrick) Shallow test MWD. PJSM, load sources. 19:15 - 21 :00 1.75 DRILL P PROD1 RIH to 3,812' 21 :00 - 21 :30 0.50 DRILL P PROD1 Make up topdrive, break circulation. Calibrate AICal tool inside casing, 500 gpm, 1810 psi, rotating string 10 rpm, torque 5.5K 21 :30 - 22:30 1.00 DRILL P PROD1 RIH to 6,000' no problems. 22:30 - 23:15 0.75 DRILL P PROD1 Circulate bottoms up, 480 gpm, 2,200 psi rotating and reciprocating pipe 80 rpm, torque 10k. up WI = 175k, dn WI = 75k 23:15 - 23:30 0.25 DRILL P PROD1 Tag cement at 6,003' set down 50k, drilled cement from 6,003' to 6,008', to confirm top of cement and not a ledge created Printed: 11/1/2004 1:50:06 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-210 Z-210 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 1 0/8/2004 1 0/31/2004 Spud Date: 10/10/2004 End: 10/31/2004 10/23/2004 23:15 - 23:30 0.25 DRILL P PROD1 form circulating. set down 50k. 23:30 - 00:00 0.50 DRILL P PROD1 Blow down topdrive, POH from 6,000' to 5,823' 10/24/2004 00:00 - 01 :00 1.00 DRILL P PROD1 POH from 5,823' to 3,812' 01 :00 - 03:00 2.00 DRILL P PROD1 Clean Pits #3 & #4, clean under shakers, take on new 9.0 ppg LSND mud in #3 & #4. 03:00 - 04:30 1.50 DRILL P PROD1 RIH to 3,994' make up topdrive begin displacement, rotating and reciprocating pipe from 3,994' to 3,900' at 500 gpm, 1490 psi, 80 rpm, torque 6.5k. Establish baseline ECD at 520 gpm, 100 rpm, ECD = 9.53 04:30 - 05:00 0.50 DRILL P PROD1 Began trenching from 3947' to 3,957' holding a 175R toolface, 500 gpm, 1505 psi, up wt = 155k, dn wt = 80k 05:00 - 08:30 3.50 STKOH P PROD1 Open hole sidetrack, time drill from 3,957' to 4,017' at 5-7 fph. for first 10' and gradually increasing wob, and ROP, 500 gpm 1505 psi, 175R toolface 08:30 - 12:00 3.50 DRILL ,P PROD1 Directional drill 8.75" main bore from 4,017' to 4,377', 10-15k wob, 550 gpm, 2,200 psi on bottom, 2,000 psi off bottom, 80 rpm, torque on bottom 5k, torque off bottom 4k, ECD = 9.9, up wt = 105k, dn wt = 85k, rt wt = 90k AST = 4.36 ART = .91 12:00 - 00:00 12.00 DRILL P PROD1 Directional drill 8.75" main bore from 4,377' to 6,099', 10-15k wob, 550 gpm, 2,700 psi on bottom, 2,450 psi off bottom, 80 rpm, torque on bottom 7k, torque off bottom 6k, ECD = 10.1, up wt = 135k, dn wt = 95k, rt wt = 11 Ok Started control drilling at 5,700' 180 fph. AST = .76 ART = 6.04 10/25/2004 00:00 - 10:00 10.00 DRILL P PROD1 Directional drill 8.75" main bore from 6,099' to 6,958', 10-15k wob, 550 gpm, 2,780 psi on bottom, 2,500 psi off bottom, 80 rpm, torque on bottom 8k, torque off bottom 6.5k, ECD = 10.1, up wt = 155k, dn wt = 100k, rt wt = 125k, control drilling at 180 fph. ART = 5.24 AST = 1.38 10:00 - 11 :00 1.00 DRILL P PROD1 Pump 50 bbl high vis sweep, 580 gpm, 3050 psi, 100 rpm, torque 8k, reciprocate full stand. 11 :00 - 12:00 1.00 DRILL P PROD1 Monitor well, POH 5 stds,pump dry job. 12:00 - 14:30 2.50 DRILL P PROD1 POH to BHA 14:30 - 16:00 1.50 DRILL P PROD1 Change out drilling jars for next well & rack back, lay down 2 flex collars and flush remaining BHA. 16:00 - 16:30 0.50 DRILL P PROD1 PJSM, handling Nuke sources, recover sources. 16:30 - 17:45 1.25 DRILL P PROD1 Down load MWD. 17:45 - 18:30 0.75 DRILL P PROD1 Lay down remaining BHA, clean floor. 18:30 - 21 :00 2.50 CASE P RUNPRD Pull wear ring, install test plug, change top rams to 7" and test door seals to 3,500 psi. 21 :00 - 23:00 2.00 CASE P RUNPRD Make dummy run with casing hanger, make up Franks tool, rig up casing tools, PJSM with Co Rep and Toolpusher 23:00 - 00:00 1.00 CASE P RUNPRD Run 7" 26# L-80 BTC-M casing as per running detail, filling every joint. 10/26/2004 00:00 - 04:00 4.00 CASE P RUNPRD Run 7" 26# L-80 BTC-M casing (92 jts.) to 3,802' filling casing every joint. 04:00 - 05:00 1.00 CASE P RUNPRD Circulate 1 1/2 times casing volume 217 bbls, stage pumps up to 8 bpm, 650 psi, no losses. 05:00 - 07:00 2.00 CASE P RUNPRD Run 7" 26# L-80 BTC-M casing from 3,802' to 5,691' - started to see 20K to 25K Drag. 07:00 - 10:00 3.00 CASE P RUNPRD Wash Casing down, started packing off. Worked casing and Printed: 11/1/2004 1 :50:06 PM legal Well Name: 2-210 Common Well Name: 2-210 Spud Date: 10/10/2004 Event Name: DRlll+COMPlETE Start: 10/8/2004 End: 1 0/31 /2004 Contractor Name: NABORS ALASKA DRilLING I Rig Release: 1 0/31/2004 Rig Name: NABORS 7ES Rig Number: 10/26/2004 07:00 - 10:00 3.00 CASE Ip RUNPRD regained full circulation. Continued washing down to 6,007'. Unable to wash down further. Mud coming back had 160 I viscosity and PH climbed to 12.2, indicating cement contamination. Determined that casing is in old pilot hole on top of abandonment plug. 10:00 - 10:30 0.50 CASE N DPRB RUNPRD Circulate while reciprocating casing. No excessive drag. 10:30 - 16:30 6.00 CASE N DPRB RUNPRD POH UD 7" Casing to 3,800' - above 9 5/8" shoe. 16:30 - 18:00 1.50 CASE N DPRB RUNPRD Circulate & condition mud. Stage pumps up to 6 BPM 1425 psi. Reciprocate w/150K up wt. & 75K dn wt. 18:00 - 00:00 6.00 CASE N DPRB RUNPRD Continue POH & L/D 7" Casing. PJSM & fill out applicable permits and sniff area for gas. . Heat w/ rosebud and break out bakerloked Shoe track. Float equipment & threads of shoe track in good shape and will re-run. 10/27/2004 00:00 - 00:30 0.50 CASE N DPRB RUNPRD RID Tongs. Clear & clean floor. 00:30 - 02:30 2.00 CASE N DPRB RUNPRD CIO top set of pipe rams back to 3" X 6" variables & test to I~ 3500 psi. 02:30 - 03:30 1.00 CASE DPRB RUNPRD Install wear bushing. Change out bails. 03:30 - 06:00 2.50 CASE DPRB RUNPRD P/U Clean out BHA, Surface test MWD & continue M/U BHA. 06:00 - 10:00 4.00 CASE N DPRB RUNPRD RIH to 3,856'. Orient motor to 180 degrees. Worked through "New Hole". Survey @ 4,100' confirmed we are in "New Hole". Continue RIH to 4,923' to position mill & reamer at sidetrack point. 10:00 - 11 :00 1.00 CASE N DPRB RUNPRD Ream mill & reamer through sidetrack point. Pumping @ 550 GPM wI 2100 psi. Reciprocating & rotating @ 90 RPM. 11 :00 - 13:00 2.00 CASE N DPRB RUNPRD Continue RIH. Wash through 6,170' & continue RIH to TD @ 6,958' with no problems. 13:00 - 14:30 1.50 CASE N DPRB RUNPRD Pump Hi-Vis sweep. C&C Mud @ 500 GPM & 2500 psi. 14:30 - 16:00 1.50 CASE N DPRB RUNPRD POH to again position mill & reamer at sidetrack point. 16:00 - 16:45 0.75 CASE N DPRB RUNPRD Ream mill & reamer through sidetack point as before. Spot nut-plug pill. 16:45 - 17:30 0.75 CASE N DPRB RUNPRD Continue POH to 4,044'. 17:30 - 18:45 1.25 CASE N DPRB RUNPRD Orient & dress sidetrack point. After dressing pull up above sidetrack and orient high side. RIH wI no pump to 4,230'. Take survey and confirm still in "New Hole". 18:45 - 20:30 1.75 CASE N DPRB RUNPRD Pump dry job & POH to BHA. 20:30 - 22:30 2.00 CASE N DPRB RUNPRD Lay down Clean-out BHA. 22:30 - 00:00 1.50 CASE N DPRB RUNPRD CleaJ & clean floor. Pull wear bushing. C/O top rams from 3.5" X 6" variables to 7" casing rams. 10/28/2004 00:00 - 01 :00 1.00 CASE N DPRB RUNPRD Complete installing 7" casing rams and test bonnet seals to 4000 psi. 01 :00 - 02:30 1.50 CASE N DPRB RUNPRD Rig up to run 7" production casing. Hold PJSM with Crew, Toolpusher, Co. Man and casing hand. 02:30 - 07:30 5.00 CASE N DPRB RUNPRD Re-run 7", 26#, L-80, BTC-M Production Casing. Make up Shoe track and check floats. Continue running casing, centralizing as per program. Fill pipe every joint. Run casing to 9 5/8" casing shoe at 3811' 07:30 - 08:30 1.00 CASE N DPRB RUNPRD Circulate 1 1/2 casing volume at 8 bpm, 600 spi. Pick up weight 127K slack off 75K. 08:30 - 09:00 0.50 CASE N DPRB RUNPRD Run 7" casing to 4709' (114 joints) wth the 7" casing shoe 100' into nut-plug pill. 09:00 - 09:30 0.50 CASE N DPRB RUNPRD Circulate at 7 bpm 650 psi. Reciprocate casing. Recover good sample of nut-plug to confirm the casing is in the main bore. 09:30 - 10:45 1.25 CASE N DPRB RUNPRD Run 7", 26#, L-80, BTC-M production casing to 6016' (146 Printed: 11/1/2004 1 :50:06 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-210 Z-210 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 10/8/2004 1 0/31/2004 Spud Date: 10/10/2004 End: 10/31/2004 10/28/2004 09:30 - 10:45 1.25 CASE N DPRB RUNPRD joints) 10:45 - 12:30 1.75 CASE P RUNPRD Run 7",26#. L-80, BTC-M production casing from 6016' to 6958' (168 joints) 12:30 - 13:00 0.50 CEMT P RUNPRD Circulate one bottoms up through Franks Tool @ 6.5 BPM I 650 psi. Up Wt = 250K, Dn. Wt. = 90K. 13:00 - 13:30 0.50 CEMT P RUNPRD RID Ftranks Tool & MIU Cement Head. 13:30 - 15:30 2.00 CEMT P RUNPRD Circulate & condition Mud & Hole. 7 BPM I 600 psi. Reciprocating casing 15 ft. 250k - Up, 90K - On. 15:30 - 17:15 1.75 CEMT P RUNPRD Cement as per Program: Turn over to Schlumberger - Fill & pressure test lines to 4000 psi. Pump 15 Bbls of CW-100 @ 9.3 ppg, followed by 30 Bbls of 10.3 ppg MudPush. Drop Bottom Plug. Pump 67 Bbls of Batch Mixed, 15.8 ppg, Class 'G', Gasblok Tail Slurry wI 1.2 cu/ft per sk yield. All pumped @ 6 BPM. Wash cement to 'Tee' and drop Top Plug. Switch to Rig and displace with 263 Bbls of clean 8.5 ppg. Seawater. Final pumping pressure at bump was 1900 psi. Walk pressure up to 4000 psi. 17:15 - 17:45 0.50 CASE P RUNPRD Chart and hold 4000 psi on casing for 30 minute test. 17:45 - 19:00 1.25 CASE P RUNPRD R/D Cement head, Back out & UD Landing Jt. & drain stack. 19:00 - 19:30 0.50 CASE P RUNPRD Install Pack-off. R.I.L.D.S. Test Pack-off to 5000 psi for 10 minutes - OK. 19:30 - 21:30 2.00 RUNPRD Change out 7" Casing Rams to 3.5" X 6" Variables. 21 :30 - 00:00 2.50 RUNPRD Test BOPE to 250 psi Low & 4000 psi High as per AOGCC Permit to Drill. 10/29/2004 00:00 - 03:00 3.00 RUNPRD Complete testing BOPE to 250 psi Low & 4000 psi High. Test witnessed by John Crisp, AOGCC. 03:00 - 04:00 1.00 CASE RUNPRD RID all test equipment. Install! wear bushing. 04:00 - 04:30 0.50 PERFO OTHCMP P/U and install bails & elevators. 04:30 - 06:00 1.50 PERFO OTHCMP Slip & Cut Drilling Line. Service Top Drive. 06:00 - 08:30 2.50 PERFO OTHCMP Hold PJSM with rig crew, Toolpusher, Company Man and Schlumberger TCP tech. Make up 4 1/2" HSD perforating guns, balnk spacers and electronic firing system. Make up debris sub, bumper sub, LWD Gamma Ray and 4" drill pipe pup joint. 08:30 - 18:00 OTHCMP RIH with TCP perforating assembly to 6100'. Log down attempt to locate RA marker in 7" casing at 5768'. Located RA marker but GR signal very weak. Make several passes. RIH to locate RA marker at 6316'. Good indication on GR. Repeat log across marker. RIH to 7" casing float collar at 6867' to confirm depths. Pull back to RA marker at 6316', log down to locate sand below RA marker with GR. Position guns on depth. SEE REMARKS FOR SIMULTANEOUS OPERATION. 18:00 - 19:00 1.00 PERFO P OTHCMP Displace well bore to 9.0 ppg. Brine. 19:00 - 20:00 1.00 PERFO P OTHCMP Close annular preventer and practice firing sequences through choke. When timing right: iniate firing sequence and fire 4.5" guns, 5 spf, total 701 shots - top shot @ 6366' - bottom shot @ 6654'. Definite surface indication of firing. Open annular, pull up 30 ft. - no excess drag. Pump across hole from trip tank and monitor well. Took no fluid - well static. 20:00 - 21 :00 1.00 PERFO OTHCMP Circulate with 9.0 ppg brine @ 400 GPM & 800 psi. 21 :00 - 00:00 3.00 PERFO OTHCMP POH Stand back 21 stands of 4" DP. Continue POH laying down 4" DP. 10/30/2004 00:00 - 01 :00 1.00 OTHCMP POH UD 4" DP. Printed: 11/1/2004 1 :50:06 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02:00 - 04:45 04:45 - 10:00 10:00 - 15:30 Z-210 Z-210 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 10/8/2004 1 0/31/2004 Spud Date: 10/10/2004 End: 10/31/2004 2.75 Lay down perforating firing head BHA - LWD, Bumper-Sub, XO's & 2 stands of DP. OTHCMP PJSM with DPC tech & crew on laying down gun. Rig up power tongs. Lay down 14 ea, 4.5" Guns. All fired save 3 single shots on bottom gun. Clear floor and rig down power tongs and handling tools. OTHCMP PJSM with Schlumberger E-line crew. Rig up E-line unit. Make up 6.165" Gauge Ring, Junk Basket and GR, run in to 1628'. Held up,tool tight. Work tool free and POH. Change gauge ring to 6.05" and RIH to 6800'. Tool tight on bottom. Work tool free. POH. Rrecovered 2.5 gal of cement in junk basket. Lay down gauge ring, junk basket and GR. Pick up US IT logging tool and RIH to 6700'. Log for cement quality and perforation intervals. Excellent cement throughout perforated interval and good isolation above injection zone. TOC = 481 0'. POH. Lay down logging tools. Rig down Schlumberger E-line unit. Pull Wear Bushing & make dummy run with Tubing Hanger & Landing Jt. R/U to run Completion. PJSM with Co Man, TP, Casing hand, Baker Tech, & Crew. Run 3.5" TC-II completion equipment followed by 4.5" TC-II Tubing as per program. Remote Torque / Turn box on Tubing tongs quit counting turns. Called for replacement - delivered from Deadhorse. Hook up same & test - OK. Completed RIH with 4.5", 12.6#,L-80, TCII Tubing. Total 148 Jts. ran. Make up FMC tubing hanger and landing joint. RIH. Land string and run in lock down screws (R.I.L.D.S.) Rig up to reverse circulate. Reverse circulate 65 Bbls of corrosion inhibited 9.0 ppg brine at 3 BPM /100 psi.. Drop Ball/Rod. Pressure down tubing 4200 psi. to set all four Premium Packers. Hold 4200 psi & Chart for 30 minute tubing test. Bleed tubing to 2500 psi. Pressure down annulus 4000 psi. Chart and hold for 30 minute test on top packer. Bleed off annulus, then tubing. Pressure annulus to 2750 psi to shear DCK valve. Pump through both ways to insure full shear. RUNCMP R/D landing Jt. & blow down circulating lines. OTHCMP Set TWC & test from above to 1000 psi & hold for 30 minutes. OTHCMP N/D BOPE OTHCMP N/U Adapter Flange & Tree. OTHCMP Test Pack-Off, Adaapter Flange & Tree to 5000 psi. OTHCMP R/U DSM lubricastor & pull TWC. OTHCMP R/U circulating / U-tube manifold to Tree. R/U Little Red. PJSM with all hands. Little Red pressure test lines to 4000 psi. Reverse 95 Bbls of 85 degree, diesel down 4.5" X 7" annulus. Allow to U-Tube to freeze protect to 2200' TVD / 2774' MD. OTHCMP R/D Circulating manifold. R/U DSM lubricator & set BPV & VR Plugs. Test under BPV to 1000 psi. Bleed to '0'. Secure Tree. RELEASE RIG @ 18:00 HRS, 10/31/2004. WILL MOVE TO Z-13A 5.25 EV AL P 5.50 EV AL P IOTHCMP I ! RUNCMP RUNCMP RUNCMP SFAL RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP 15:30 - 16:30 1.00 16:30 - 18:00 1.50 18:00 - 23:00 5.00 RUNCO 23:00 - 00:00 1.00 10/31/2004 00:00 - 04:30 4.50 04:30 - 05:00 0.50 RUNCO 05:00 - 05:30 0.50 RUNCO 05:30 - 06:00 0.50 RUNCO 06:00 - 08:00 2.00 RUNCO 08:00 - 08:30 08:30 - 09:30 09:30 - 10:30 10:30 - 13:00 13:00 - 13:30 13:30 - 14:45 14:45 - 16:30 16:30 - 18:00 0.50 RUNCO 1.00 BOPSU P 1.00 BOPSU P 2.50 WHSUR P 0.50 WHSUR P 1.25 WHSUR P 1.75 WHSUR P 1.50 WHSUR P Printed: 11/1/2004 1 :50:06 PM . . 11-Nov-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well Z-210 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 3,925.24 I MD 3,957.00 I MD 6,858.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date J r ¡Yr.; ;ZU, VI 1~~ {j~' l ( ¡ . !: ; Signed .. _. ' . (lw I Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ... BP EXPLORA TION (ALASKA) INC. North Slope Alaska BPXA Z-210 Job No. AKZZ3328880, Surveyed: 25 October, 2004 Survey Report 9 November, 2004 Your Ref: API 500292322600 Surface Coordinates: 5959359.95 N, 599094.79 E (700 17' 54.2868" N, 210048' 09.0477" E) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 81.90ft above Mean Sea Level sl::J,e............y-·SU'1'1 [)R.IL LING SeR.VICeS A Halliburton Company EFt ITI E . . Survey Ref: svy4436 BP EXPLORA TION (ALASKA) INC. Survey Report for Z-210 Your Ref: AP/500292322600 Job No. AKZZ3328880, Surveyed: 25 October, 2004 North Slope A/aska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) n100ft) 3925.24 55.920 85.250 2811.56 2893.46 619.93 N 2084.66 E 5960007.32 N 601171.09E 2172.91 Tie On Point 3957.00 55.770 85.100 2829.39 2911.29 622.14 N 2110.85 E 5960009.87 N 601197.25 E 0.613 2198.39 Window Point 4020.22 49.680 87.760 2867.67 2949.57 625.32 N 2161.02E 5960013.71 N 601247.38 E 10.197 2246.87 4116.08 48.390 89.830 2930.52 3012.42 626.85 N 2233.38 E 5960016.20 N 601319.71 E 2.114 2315.79 4212.69 48.330 95.050 2994.73 3076.63 623.78 N 2305.47 E 5960014.08 N 601391.83 E 4.038 2382.95 4308.34 46.990 100.070 3059.18 3141.08 614.52 N 2375.51 E 5960005.74 N 601461.99 E 4.124 2446.16 e< 4405.48 45.070 104.000 3126.63 3208.53 599.99 N 2443.87 E 5959992.11 N 601530.53 E 3.519 2506.06 4501.23 44.400 107.930 3194.66 3276.56 581.47 N 2508.64 E 5959974.45 N 601595.54 E 2.972 2561 .27 4595.06 43.890 109.590 3261.99 3343.89 560.46 N 2570.51 E 5959954.26 N 601657.69 E 1.347 2612.94 4691.06 43.490 109.380 3331.41 3413.31 538.34 N 2633.03 E 5959932.96 N 601720.49 E 0.443 2664.84 4785.08 43.830 109.600 3399.43 3481.33 516.68 N 2694.22 E 5959912.12 N 601781.96 E 0.396 2715.65 4881.79 43.900 109.190 3469.16 3551.06 494.43 N 2757.43 E 5959890.70 N 601845.46 E 0.303 2768.17 4977.68 43.510 109.290 3538.47 3620.37 472.60 N 2819.98 E 5959869.69 N 601908.30 E 0.413 2820.21 5073.47 43.350 109.450 3608.04 3689.94 450.76 N 2882.11 E 5959848.67 N 601970.70 E 0.203 2871.84 5169.14 43.090 109.660 3677.76 3759.66 428.83 N 2943.85 E 5959827.56 N 602032.72 E 0.311 2923.07 5264.58 42.620 109.570 3747.72 3829.62 407.04 N 3004.99 E 5959806.58 N 602094.15 E 0.497 2973.79 5360.35 43.560 109.410 3817.66 3899.56 385.21 N 3066.67 E 5959785.56 N 602156.11 E 0.988 3025.00 5456.87 43.460 108.720 3887.66 3969.56 363.50 N 3129.47 E 5959764.69 N 602219.20 E 0.503 3077.32 5552.20 43.170 108.580 3957.02 4038.92 342.59 N 3191.44E 5959744.59 N 602281.43 E 0.320 3129.10 5646.53 44.860 110.060 4024.86 4106.76 320.90 N 3253.28 E 5959723.72 N 602343.56 E 2.097 3180.51 5743.56 45.560 110.890 4093.22 4175.12 296.81 N 3317.79 E 5959700.48 N 602408.38 E 0.943 3233.66 5838.30 43.890 108.440 4160.53 4242.43 274.35 N 3380.55 E 5959678.86 N 602471.43 E 2.533 3285.69 5934.84 43.600 108.510 4230.28 4312.18 253.20 N 3443.86 E 5959658.54 N 602535.01 E 0.305 3338.67 . 6029.98 43.410 108.940 4299.28 4381.18 232.18 N 3505.89 E 5959638.34 N 602597.32 E 0.370 3390.47 6126.73 43.080 108.270 4369.76 4451.66 211.03 N 3568.71 E 5959618.02 N 602660.41 E 0.584 3442.99 6222.87 42.970 1 08.480 4440.04 4521.94 190.35 N 3630.97 E 5959598.16 N 602722.93 E 0.188 3495.12 6317.35 42.840 107.780 4509.25 4591.15 170.33 N 3692.09 E 5959578.95 N 602784.31 E 0.523 3546.40 6412.79 40.170 108.010 4580.72 4662.62 150.90 N 3752.27 E 5959560.32 N 602844.75 E 2.802 3596.97 6508.83 37.250 108.080 4655.65 4737.55 132.30 N 3809.38 E 5959542.47 N 602902.09 E 3.041 3644.91 6603.56 33.760 110.420 4732.76 4814.66 114.21 N 3861.32 E 5959525.07 N 602954.26 E 3.953 3688.13 6699.77 31.020 112.790 4814.00 4895.90 95.28 N 3909.23 E 5959506.77 N 603002.43 E 3.138 3727.27 6796.04 30.770 111.970 4896.61 4978.51 76.46 N 3954.94 E 5959488.55 N 603048.38 E 0.509 3764.36 6890.04 30.270 111.590 4977.58 5059.48 58.75 N 3999.27 E 5959471.43 N 603092.94 E 0.570 3800.51 6958.00 30.270 111.590 5036.28 5118.18 46.14 N 4031 .12 E 5959459.24 N 603124.95 E 0.000 3826.52 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. 9 November, 2004 - 10:58 Page 2 of 3 DrillQuest 3.03.06.006 BP EXPLORA TION (ALASKA) INC. Survey Report for Z-210 Your Ref: API 500292322600 Job No. AKZZ3328880, Surveyed: 25 October, 2004 North Slope Alaska BPXA Global Northings and Eastings are relative to t~AD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 71.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 6958.00fl., The Bottom Hole Displacement is 4031.39fl., in the Direction of 89.344° (True). Comments e Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 3925.24 3957.00 6958.00 2893.46 2911.29 5118.18 619.93 N 622.14 N 46.14 N 2084.66 E 2110.85E 4031 .12 E Tie On Point Window Point Projected Survey Survey toollJroç¡ram for Z-210 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 648.71 0.00 647.65 648.71 6958.00 647.65 BP High Accuracy Gyro - GYD-CT-DMS (Z-210PB1) 5118.18 MWD+IIFR+MS (Z-210PB1) e 9 November, 2004 - 10:58 Page 3 of 3 DrillQuest 3.03.06.006 . . 11-Nov-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well Z-210 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 3,925.24' MD 3,957.00' MD 6,958.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date I)" It! Qu ~'i /7 ( j /'/1" / Signed ~ C./ . 'l Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) BP EXPLORA TION (ALASKA) INC. North Slope Alaska BPXA Z-210 (mwd) . Job No. AKMW3328880, Surveyed: 25 October, 2004 Survey Report 9 November, 2004 Your Ref: API 500292322600 Surface Coordinates: 5959359.95 N, 599094.79 E (70· 17' 54.2868" N, 210· 48' 09.0477" E) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 81. 90ft above Mean Sea Level . SI:JE!I"""'I"""'Y-SUI'1 CFtILL.ING SeFtVICes A Halliburton Company Survey Ref: svy4437 BP EXPLORA TION (ALASKA) INC. Survey Report for Z-210 (mwd) Your Ref: API 500292322600 Job No. AKMW3328880, Surveyed: 25 October, 2004 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3925.24 55.920 85.180 2811.57 2893.47 628.27 N 2083.61 E 5960015.64 N 601169.94 E 2174.64 Tie On Point 3957.00 55.770 85.100 2829.40 2911.30 630.49 N 2109.80 E 5960018.21 N 601196.09 E 0.516 2200.12 Window Point 4020.22 49.680 86.940 2867.67 2949.57 634.02 N 2159.96 E 5960022.39 N 601246.20 E 9.907 2248.69 4116.08 48.390 89.820 2930.52 3012.42 636.08 N 2232.30 E 5960025.41 N 601318.50 E 2.638 2317.76 4212.69 48.330 94.210 2994.73 3076.63 633.54 N 2304.42 E 5960023.82 N 601390.65 E 3.396 2385.13 4308.34 46.990 98.860 3059.18 3141.08 625.53 N 2374.62 E 5960016.74 N 601460.96 E 3.856 2448.90 . 4405.48 45.070 102.820 3126.63 3208.53 612.43 N 2443.27 E 5960004.54 N 601529.77 E 3.537 2509.54 4501.23 44.400 107.130 3194.66 3276.56 595.04 N 2508.34 E 5959988.01 N 601595.07 E 3.244 2565.41 4595.06 43.890 109.060 3262.00 3343.90 574.75 N 2570.46 E 5959968.54 N 601657.44 E 1.532 2617.53 4691.06 43.490 108.840 3331.41 3413.31 553.21 N 2633.17 E 5959947.83 N 601720.44 E 0.446 2669.82 4785.08 43.830 109.250 3399.43 3481.33 532.03 N 2694.53 E 5959927.46 N 601782.07 E 0.471 2720.94 4881.79 43.900 109.040 3469.16 3551.06 510.05 N 2757.84 E 5959906.32 N 601845.66 E 0.167 2773.64 4977.68 43.510 109.110 3538.47 3620.37 488.40 N 2820.46 E 5959885.50 N 601908.56 E 0.410 2825.80 5073.47 43.350 109.270 3608.04 3689.94 466.75 N 2882.65 E 5959864.67 N 601971.03 E 0.203 2877.56 5169.14 43.090 109.540 3677.76 3759.66 444.99 N 2944.44 E 5959843.72 N 602033.11 E 0.333 2928.90 5264.58 42.620 109.250 3747.72 3829.62 423.43 N 3005.67 E 5959822.98 N 602094.62 E 0.534 2979.77 5360.35 43.560 109.110 3817.66 3899.56 401.94 N 3067.46 E 5959802.30 N 602156.69 E 0.987 3031.20 5456.87 43.460 108.080 3887.66 3969.56 380.75 N 3130.45 E 5959781.94 N 602219.94 E 0.742 3083.85 5552.20 43.170 108.390 3957.02 4038.92 360.28 N 3192.56 E 5959762.30 N 602282.32 E 0.377 3135.92 5646.53 44.860 110.170 4024.86 4106.76 338.63 N 3254.42 E 5959741.46 N 602344.46 E 2.220 3187.36 5743.56 45.560 110.720 4093.22 4175.12 314.57 N 3318.94 E 5959718.26 N 602409.29 E 0.826 3240.53 5838.30 43.890 108.350 4160.53 4242.43 292.27 N 3381.75 E 5959696.78 N 602472.39 E 2.491 3292.66 5934.84 43.600 108.420 4230.28 4312.18 271.21 N 3445.10 E 5959676.57 N 602536.01 E 0.305 3345.70 . 6029.98 43.410 108.900 4299.28 4381.18 250.26 N 3507.15 E 5959656.43 N 602598.33 E 0.401 3397.55 6126.73 43.080 108.360 4369.76 4451.66 229.08 N 3569.96 E 5959636.09 N 602661.42 E 0.512 3450.05 6222.87 42.970 109.410 4440.04 4521.94 207.85 N 3632.03 E 5959615.67 N 602723.76 E 0.754 3501.82 6317.35 42.840 108.070 4509.25 4591.15 187.19 N 3692.93 E 5959595.82 N 602784.93 E 0.975 3552.68 6412.79 40.170 107.740 4580.72 4662.62 167.74 N 3753.11 E 5959577.16 N 602845.36 E 2.807 3603.24 6508.83 37.250 108.170 4655.65 4737.55 149.23 N 3810.24 E 5959559.41 N 602902.73 E 3.053 3651.24 6603.56 33.760 110.400 4732.76 4814.66 131.11 N 3862.17 E 5959541 .98 N 602954.90 E 3.929 3694.44 6699.77 31.020 112.890 4814.00 4895.90 112.14N 3910.08 E 5959523.64 N 603003.05 E 3.167 3733.56 6796.04 30.770 111.960 4896.61 4978.51 93.29 N 3955.77 E 5959505.39 N 603048.98 E 0.560 3770.62 6890.04 30.270 111.300 4977.59 5059.49 75.69 N 4000.14 E 5959488.38 N 603093.59 E 0.640 3806.85 6958.00 30.270 111.300 5036.28 5118.18 63.25 N 4032.06 E 5959476.36 N 603125.66 E 0.000 3832.98 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. 9 November, 2004 - 10:59 Page 2 of 3 DrillQuest 3.03.06.006 North Slope Alaska BP EXPLORA TION (ALASKA) INC. Survey Report for Z-210 (mwd) Your Ref: API 500292322600 Job No. AKMW3328880, Surveyed: 25 October, 2004 Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. BPXA The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 71.000· (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 6958.00ft., The Bottom Hole Displacement is 4032.55ft., in the Direction of 89.101· (True). Comments Measured Depth (ft) 3925.24 3957.00 6958.00 . Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 2893.47 2911.30 5118.18 628.27 N 630.49 N 63.25 N 2083.61 E 2109.80 E 4032.06 E Tie On Point Window Point Projected Survey Survey too/program for 2-210 (mwd) From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 648.71 0.00 647.65 648.71 6958.00 . 647.65 BP High Accuracy Gyro - GYD-CT-DMS (Z-210PB1 (mwd)) 5118.18 MWD Magnetic (Z-210PB1 (mwd)) 9 November, 2004 - 10:59 Page 3 of 3 DrillQuest 3.03.06.006 . . 11-Nov-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well Z-210 PB1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 7,900.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AI< 99518 . /U 1\ / I Date /t ¡1f I v ÄC\ IN Signed I ' f'*'t Û'J.) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) lYE , EFI . BP EXPLORA TION (ALASKA) INC. North Slope Alaska BPXA Z-210PB1 Job No. AKZZ3328880, Surveyed: 16 October, 2004 Survey Report 2004 9 November, . Survey Ref: svy4410 Your Ref: API 500292322670 Surface Coordinates: 5959359.95 N, 599094.79 E (70· 17' 54.2868" N, 210· 48' 09.0477" E) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 81.90ft above Mean Sea Level SPE!ï'ï'Y-SUI'! DBJL.L.JNG__ seRViCeS A Halliburton Company BP EXPLORA TION (ALASKA) INC. Survey Report for Z-210PB1 Your Ref: API 500292322670 Job No. AKZZ3328880, Surveyed: 16 October, 2004 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 DOft) 0.00 0.000 0.000 -81.90 0.00 0.00 N 0.00 E 5959359.95 N 599094.79 E 0.00 BP High Accuracy Gyro - GYD·C1 OMS 106.50 0.710 197.690 24.60 106.50 0.63 S 0.20W 5959359.32 N 599094.60 E 0.667 -0.39 163.50 0.800 169.180 81.59 163.49 1.36 S 0.23W 5959358.59 N 599094.57 E 0.670 -0.66 254.50 3.380 47.640 172.54 254.44 0.17 S 1.87 E 5959359.80 N 599096.66 E 4.241 1.71 343.00 3.610 43.330 260.88 342.78 3.61 N 5.71 E 5959363.64 N 599100.45 E 0.394 6.57 . 436.30 1.330 12.980 354.09 435.99 6.80N 7.97 E 5959366.86 N 599102.67 E 2.735 9.75 486.60 2.360 359.900 404.36 486.26 8.41 N 8.10 E 5959368.47 N 599102.78 E 2.199 10.39 559.50 5.040 18.650 477.11 559.01 12.95 N 9.12 E 5959373.01 N 599103.74 E 3.986 12.84 648.71 7.790 13.090 565.75 647.65 22.55 N 11.74 E 5959382.65 N 599106.23 E 3.157 18.44 MWD+IIFR+MS 677.85 8.940 19.260 594.58 676.48 26.61 N 12.94 E 5959386.73 N 599107.37 E 5.001 20.89 770.98 10.800 27.180 686.33 768.23 41.21 N 19.31 E 5959401.41 N 599113.55 E 2.468 31.67 861.05 11.010 35.340 774.78 856.68 55.73 N 28.14 E 5959416.05 N 599122.19 E 1.728 44.75 964.53 13.730 41.180 875.85 957.75 73.04 N 41.94E 5959433.53 N 599135.77 E 2.890 63.44 1060.37 17.860 48.690 968.06 1049.96 91.31 N 60.48 E 5959452.05 N 599154.06 E 4.800 86.91 1156.29 20.830 57.960 1058.58 1140.48 110.07 N 86.00 E 5959471.15 N 599179.33 E 4.445 117.15 1219.84 23.540 63.810 1117.43 1199.33 121.67N 106.97 E 5959483.02 N 599200.15 E 5.497 140.76 1250.51 25.620 65.460 1145.32 1227.22 127.13 N 118.50 E 5959488.63 N 599211.60 E 7.141 153.43 1283.65 27.350 66.190 1174.98 1256.88 133.18 N 131.98E 5959494.86 N 599225.01 E 5.312 168.15 1347.66 29.820 67.780 1231.18 1313.08 145.14 N 160.17 E 5959507.19 N 599253.04 E 4.037 198.70 1443.26 32.790 69.180 1312.86 1394.76 163.33 N 206.39 E 5959525.99 N 599299.00 E 3.198 248.32 1538.97 35.210 70.170 1392.20 1474.10 181.91 N 256.57 E 5959545.22 N 599348.94 E 2.594 301.82 1634.37 37.680 69.930 1468.93 1550.83 201.24 N 309.84 E 5959565.26 N 599401.95 E 2.593 358.48 . 1729.70 41 .450 69.610 1542.41 1624.31 222.24 N 366.80 E 5959587.01 N 599458.63 E 3.960 419.17 1791.36 46.830 70.310 1586.64 1668.54 236.94 N 407.13 E 5959602.24 N 599498.76 E 8.761 462.09 1825.82 51.120 69.390 1609.26 1691.16 245.90 N 431.53 E 5959611.52 N 599523.04 E 12.611 488.08 1857.16 54.270 68.200 1628.25 1710.15 254.92 N 454.77 E 5959620.84 N 599546.15 E 10.495 512.98 1890.07 55.140 65.990 1647.27 1729.17 265.38 N 479.50 E 5959631.63 N 599570.75 E 6.085 539.78 1921.13 55.610 63.090 1664.92 1746.82 276.36 N 502.58 E 5959642.92 N 599593.68 E 7.830 565.17 1952.87 55.300 61.980 1682.92 1764.82 288.42 N 525.77 E 5959655.28 N 599616.71 E 3.042 591.03 2017.02 54.020 62.430 1720.02 1801.92 312.82 N 572.06 E 5959680.29 N 599662.68 E 2.076 642.74 2112.86 57.600 62.230 1773.87 1855.77 349.63 N 642.26 E 5959718.02 N 599732.38 E 3.739 721.10 2205.66 59.800 61.960 1822.08 1903.98 386.74 N 712.33 E 5959756.05 N 599801.96 E 2.384 799.43 2301.50 56.940 64.260 1872.34 1954.24 423.67 N 785.08 E 5959793.93 N 599874.22 E 3.616 880.24 2397.35 54.890 66.350 1926.06 2007.96 456.84 N 857.19 E 5959828.06 N 599945.88 E 2.799 959.22 2492.33 54.130 69.450 1981.21 2063.11 485.94 N 928.82 E 5959858.10 N 600017.12 E 2.775 1036.42 9 November, 2004 - 10:58 Page 20f5 Dril/Quest 3.03.06.006 BP EXPLORA TION (ALASKA) INC. Survey Report for Z·210PB1 Your Ref: API 500292322670 Job No. AKZZ3328880, Surveyed: 16 October, 2004 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth (ncl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 2587.60 52.080 73.330 2038.41 2120.31 510.28 N 1000.99 E 5959883.38 N 600088.96 E 3.903 1112.59 2684.08 52.400 76.590 2097.50 2179.40 530.06 N 1074.64 E 5959904.14 N 600162.34 E 2.692 1188.66 2779.28 52.200 80.180 2155.73 2237.63 545.23 N 1148.40 E 5959920.27 N 600235.90 E 2.991 1263.34 2874.99 52.710 83.480 2214.07 2295.97 556.00 N 1223.50 E 5959932.04 N 600310.85 E 2.785 1337.85 2970.82 55.010 86.010 2270.59 2352.49 563.06 N 1300.55 E 5959940.11 N 600387.80 E 3.210 1413.01 3065.96 54.790 86.340 2325.29 2407.19 568.25 N 1378.21 E 5959946.33 N 600465.39 E 0.366 1488.13 . 3161.71 55.270 86.810 2380.17 2462.07 572.94 N 1456.53 E 5959952.05 N 600543.64 E 0.643 1563.71 3257.42 55.470 87.080 2434.56 2516.46 577.14 N 1535.18E 5959957.28 N 600622.22 E 0.312 1639.43 3353.16 54.750 86.780 2489.32 2571.22 581.34 N 1613.59 E 5959962.52 N 600700.58 E 0.795 1714.95 3449.13 54.870 85.410 2544.63 2626.53 586.68 N 1691.84 E 5959968.89 N 600778.75 E 1.173 1790.67 3544.54 55.910 84.790 2598.82 2680.72 593.39 N 1770.08 E 5959976.63 N 600856.89 E 1.214 1866.83 3638.86 55.530 84.400 2651.95 2733.85 600.74 N 1847.67 E 5959985.00 N 600934.37 E 0.528 1942.58 3734.71 56.380 85.620 2705.61 2787.51 607.64 N 1926.78 E 5959992.94 N 601013.39 E 1.378 2019.64 3771.53 56.360 85.610 2726.00 2807.90 609.98 N 1957.35 E 5959995.69 N 601043.93 E 0.059 2049.30 3828.19 56.270 85.680 2757.43 2839.33 613.56 N 2004.36 E 5959999.89 N 601090.89 E 0.189 2094.92 3925.24 55.920 85.250 2811.56 2893.46 619.93 N 2084.66 E 5960007.32 N 601171.09 E 0.515 2172.91 4020.35 55.480 84.800 2865.16 2947.06 626.74 N 2162.93 E 5960015.16 N 601249.27 E 0.606 2249.14 4116.30 54.500 84.540 2920.21 3002.11 634.04 N 2241.18 E 5960023.49 N 601327.41 E 1.045 2325.50 4212.21 55.730 85.980 2975.06 3056.96 640.54 N 2319.58 E 5960031.02 N 601405.72 E 1.778 2401.74 4308.01 55.190 85.420 3029.38 3111.28 646.45 N 2398.27 E 5960037.97 N 601484.33 E 0.741 2478.07 4403.63 54.440 86.040 3084.48 3166.38 652.27 N 2476.20 E 5960044.82 N 601562.18 E 0.947 2553.65 4499.08 55.900 88.670 3139.00 3220.90 655.87 N 2554.46 E 5960049.45 N 601640.37 E 2.730 2628.82 4594.49 55.070 87.920 3193.06 3274.96 658.21 N 2633.03 E 5960052.82 N 601718.92 E 1.085 2703.87 . 4690.66 54.500 88.310 3248.52 3330.42 660.79 N 2711.56 E 5960056.44 N 601797.40 E 0.679 2778.97 4786.06 55.440 87.990 3303.27 3385.17 663.32 N 2789.64 E 5960059.99 N 601875.44 E 1.023 2853.61 4881.13 56.620 86.890 3356.40 3438.30 666.84 N 2868.40 E 5960064.56 N 601954.15 E 1.569 2929.23 4977.08 58.440 84.140 3407.91 3489.81 673.19 N 2949.09 E 5960071.97 N 602034.74 E 3.073 3007.59 5072.96 59.780 80.320 3457.15 3539.05 684.33 N 3030.58 E 5960084.18 N 602116.09E 3.693 3088.27 5168.60 60.730 75.110 3504.62 3586.52 702.01 N 3111.67 E 5960102.93 N 602196.94 E 4.832 3170.70 5264.58 59.360 70.290 3552.57 3634.47 726.70 N 3191.04E 5960128.67 N 602275.97 E 4.579 3253.78 5360.02 58.040 65.790 3602.17 3684.07 757.17N 3266.65 E 5960160.13 N 602351.17 E 4.259 3335.19 5455.95 54.700 62.060 3655.30 3737.20 792.21 N 3338.39 E 5960196.12 N 602422.44 E 4.753 3414.43 5551.57 53.620 60.210 3711.29 3793.19 829.62 N 3406.27 E 5960234.42 N 602489.82 E 1.933 3490.79 5646.46 53.450 58.910 3767.69 3849.59 868.28 N 3472.06 E 5960273.94 N 602555.10 E 1.116 3565.58 5742.05 53.020 59.080 3824.90 3906.80 907.73 N 3537.70 E 5960314.25 N 602620.21 E 0.472 3640.49 9 November, 2004 - 10:58 Page 3 of 5 DrillQuest 3.03.06.006 BP EXPLORA TION (ALASKA) INC. Survey Report for Z-210PB1 Your Ref: API 500292322670 Job No. AKZZ3328880, Surveyed: 16 October, 2004 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inel. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (n) (n) (ft) (n) (ft) (n) (n) (0/100ft) 5838.37 52.720 59.210 3883.05 3964.95 947.11 N 3603.62 E 5960354.50 N 602685.61 E 0.330 3715.64 5934.01 54.420 58.990 3939.84 4021.74 986.63 N 3669.65 E 5960394.88 N 602751.11 E 1.787 3790.93 6030.12 56.340 57.600 3994.44 4076.34 1028.20 N 3736.92 E 5960437.34 N 602817.83 E 2.325 3868.08 6126.11 56.510 57.340 4047.53 4129.43 1071.21 N 3804.35 E 5960481.23 N 602884.68 E 0.287 3945.84 6221.90 57.110 57.700 4099.96 4181.86 1114.26N 3871.97 E 5960525.17 N 602951.73 E 0.701 4023.79 6316.38 55.920 57.580 4152.09 4233.99 1156.43 N 3938.53 E 5960568.22 N 603017.73 E 1.264 4100.46 . 6413.15 56.040 58.430 4206.23 4288.13 1198.93 N 4006.56 E 5960611.61 N 603085.19 E 0.739 4178.61 6508.19 55.490 57.270 4259.70 4341.60 1240.74 N 4073.08 E 5960654.29 N 603151.16 E 1.163 4255.12 6602.83 54.020 57.040 4314.31 4396.21 1282.65 N 4138.02 E 5960697.06 N 603215.53 E 1.566 4330.16 6699.71 54.040 56.940 4371.22 4453.12 1325.37 N 4203.77 E 5960740.64 N 603280.71 E 0.086 4406.24 6794.92 54.180 57.380 4427.03 4508.93 1367.20 N 4268.57 E 5960783.32 N 603344.96 E 0.402 4481.13 6891.57 54.080 57.130 4483.66 4565.56 1409.56 N 4334.45 E 5960826.54 N 603410.27 E 0.234 4557.21 6986.41 53.850 56.610 4539.46 4621.36 1451.48 N 4398.67 E 5960869.30 N 603473.94 E 0.505 4631.58 7081.83 53.690 57.940 4595.85 4677.75 1493.09 N 4463.42 E 5960911.76 N 603538.14 E 1.137 4706.35 7177.33 54.150 62.420 4652.11 4734.01 1531.44 N 4530.36 E 5960951.00 N 603604.56 E 3.821 4782.13 7273.03 55.580 67.490 4707.21 4789.11 1564.53 N 4601.24 E 5960985.02 N 603675.00 E 4.582 4859.92 7368.80 55.560 67.790 4761.36 4843.26 1594.58 N 4674.29 E 5961016.03 N 603747.65 E 0.259 4938.77 7464.40 55.350 67.830 4815.57 4897.47 1624.32 N 4747.20 E 5961046.73 N 603820.16 E 0.222 5017.40 7560.09 54.980 68.190 4870.23 4952.13 1653.73 N 4820.03 E 5961077.09 N 603892.60 E 0.495 5095.83 7655.56 54.850 67.280 4925.11 5007.01 1683.33 N 4892.33 E 5961107.64 N 603964.50 E 0.792 5173.83 7751.39 54.690 67.130 4980.39 5062.29 1713.66N 4964.49 E 5961138.92 N 604036.25 E 0.210 5251.93 7830.32 54.290 66.320 5026.23 5108.13 1739.04 N 5023.51 E 5961165.08 N 604094.94 E 0.977 5316.00 7900.00 54.290 66.320 5066.90 5148.80 1761.77N 5075.33 E 5961188.49 N 604146.45 E 0.000 5372.39 Projected Survey . All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 71.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7900.00ft., The Bottom Hole Displacement is 5372.41 ft., in the Direction of 70.857° (True). 9 November, 2004 - 10:58 Page 4 of 5 DrillQuest 3.03.06.006 BP EXPLORA TION (ALASKA) INC. Survey Report for Z-210PB1 Your Ref: API 500292322670 Job No. AKZZ3328880, Surveyed: 16 October, 2004 North Slope Alaska BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 7900.00 5148.80 1761.77 N 5075.33 E Projected Survey . Survey tool prOgram for Z-210PB1 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 648.71 0.00 647.65 648.71 7900.00 647.65 BP High Accuracy Gyro - GYD-CT-DMS 5148.80 MWD+IIFR+MS . 9 November, 2004 - 10:58 Page 50f5 DrillQuest 3.03.06.006 . . 11-Nov-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well Z-210 PB1 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 7,900.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 DateLJ'-A}<~~"\ Signed ~ ~ (. Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) BP EXPLORA TION (ALASKA) INC. North Slope Alaska BPXA Z-210PB1 (mwd) . Job No. AKMW3328880, Surveyed: 16 October, 2004 Survey Report 9 November, 2004 Your Ref: API 500292322670 Surface Coordinates: 5959359.95 N, 599094.79 E (70· 17' 54.2868" N, 210· 48' 09.0477" E) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 81.90ft above Mean Sea Level . SPE!í"r"Y-!!5Uf1 OfULl...lNêå ·!§;E:A.vIEes A Halliburton Company Survey Ref: svy4435 BP EXPLORA TION (ALASKA) INC. Survey Report for Z-210PB1 (mwd) Your Ref: API 500292322670 Job No. AKMW3328880, Surveyed: 16 October, 2004 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 0.00 0.000 0.000 -81.90 0.00 0.00 N 0.00 E 5959359.95 N 599094.79 E 0.00 BP High Accuracy Gyro - GYD-C1 DMS 106.50 0.710 197.690 24.60 106.50 0.63 S 0.20W 5959359.32 N 599094.60 E 0.667 -0.39 163.50 0.800 169.180 81.59 163.49 1.36 S 0.23W 5959358.59 N 599094.57 E 0.670 -0.66 254.50 3.380 47.640 172.54 254.44 0.17 S 1.87 E 5959359.80 N 599096.66 E 4.241 1.71 343.00 3.610 43.330 260.88 342.78 3.61 N 5.71 E 5959363.64 N 599100.45 E 0.394 6.57 . 436.30 1.330 12.980 354.09 435.99 6.80 N 7.97 E 5959366.86 N 599102.67 E 2.735 9.75 486.60 2.360 359.900 404.36 486.26 8.41 N 8.10 E 5959368.47 N 599102.78 E 2.199 10.39 559.50 5.040 18.650 477.11 559.01 12.95 N 9.12 E 5959373.01 N 599103.74 E 3.986 12.84 648.71 7.790 13.090 565.75 647.65 22.55 N 11.74 E 5959382.65 N 599106.23 E 3.157 18.44 MWD Magnetic 677.85 8.940 19.520 594.58 676.48 26.61 N 12.95 E 5959386.73 N 599107.38 E 5.081 20.90 770.98 10.800 27.600 686.33 768.23 41.16 N 19.41 E 5959401.36 N 599113.65 E 2.485 31.75 861.05 11.010 35.800 774.78 856.68 55.62 N 28.35 E 5959415.94 N 599122.40 E 1.737 44.91 964.53 13.730 41 .440 875.85 957.75 72. 84 N 42.26 E 5959433.34 N 599136.08 E 2.873 63.67 1060.37 17.860 48.890 968.06 1049.96 91.04 N 60.87 E 5959451.78 N 599154.45 E 4.792 87.19 1156.29 20.830 58.340 1058.58 1140.48 109.67 N 86.48 E 5959470.75 N 599179.82 E 4.490 117.47 1219.84 23.540 63.800 1117.43 1199.33 121.21 N 107.49 E 5959482.57 N 599200.67 E 5.354 141.10 1250.51 25.620 65.920 1145.32 1227.22 126.62 N 119.04E 5959488.13 N 599212.15 E 7.365 153.78 1283.65 27.350 66.150 1174.98 1256.88 132.62 N 132.55 E 5959494.31 N 599225.58 E 5.229 168.50 1347.66 29.820 68.050 1231.18 1313.08 144.52 N 160.76 E 5959506.57 N 599253.63 E 4.111 199.05 1443.26 32.790 69.280 1312.86 1394.76 162.57 N 207.03 E 5959525.23 N 599299.66 E 3.178 248.68 1538.97 35.210 70.180 1392.20 1474.10 181.09N 257.24 E 5959544.42 N 599349.62 E 2.583 302.18 1634.37 37.680 69.550 1468.93 1550.83 200.61 N 310.44 E 5959564.63 N 599402.56 E 2.619 358.84 . 1729.70 41.450 69.270 1542.41 1624.31 221.96 N 367.27 E 5959586.74 N 599459.10 E 3.959 419.52 1791.36 46.830 70.190 1586.64 1668.54 236.82 N 407.54 E 5959602.12 N 599499.17 E 8.787 462.44 1825.82 51.120 69.280 1609.26 1691.16 245.83 N 431.92 E 5959611.45 N 599523.43 E 12.607 488.42 1857.16 54.270 68.200 1628.25 1710.15 254.87 N 455.15 E 5959620.80 N 599546.54 E 10.418 513.33 1890.07 55.140 65.970 1647.27 1729.17 265.33 N 479.88 E 5959631.58 N 599571.13 E 6.130 540.12 1921.13 55.610 62.920 1664.92 1746.82 276.36 N 502.94 E 5959642.91 N 599594.04 E 8.221 565.51 1952.87 55.300 62.010 1682.92 1764.82 288.44 N 526.12 E 5959655.30 N 599617.06 E 2.556 591.36 2017.02 54.020 62.480 1720.02 1801.92 312.81 N 572.42 E 5959680.28 N 599663.04 E 2.083 643.08 2112.86 57.600 62.380 1773.87 1855.77 349.50 N 642.69 E 5959717.89 N 599732.81 E 3.736 721.46 2205.66 59.800 62.030 1822.08 1903.98 386.47 N 712.83 E 5959755.79 N 599802.46 E 2.392 799.81 2301.50 56.940 63.210 1872.34 1954.24 424.01 N 785.27 E 5959794.28 N 599874.40 E 3.163 880.53 2397.35 54.890 65.660 1926.05 2007.95 458.28 N 856.86 E 5959829.49 N 599945.54 E 3.009 959.38 2492.33 54.130 69.590 1981.21 2063.11 487.72 N 928.35 E 5959859.87 N 600016.62 E 3.462 1036.55 9 November, 2004· 10:59 Page 2 of5 Dri/lQuest 3.03.06.006 BP EXPLORA TION (ALASKA) INC. Survey Report for Z-210PB1 (mwd) Your Ref: API 500292322670 Job No. AKMW3328880, Surveyed: 16 October, 2004 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 2587.60 52.080 73.400 2038.42 2120.32 511.92 N 1000.56 E 5959885.02 N 600088.51 E 3.854 1112.71 2684.08 52.400 76.420 2097.50 2179.40 531.77 N 1074.19 E 5959905.84 N 600161.88 E 2.497 1188.80 2779.28 52.200 79.880 2155.73 2237.63 547.24 N 1147.89E 5959922.28 N 600235.36 E 2.883 1263.52 2874.99 52.710 83.410 2214.07 2295.97 558.26 N 1222.95 E 5959934.28 N 600310.27 E 2.972 1338.07 2970.82 55.010 85.860 2270.59 2352.49 565.47 N 1299.99 E 5959942.51 N 600387.21 E 3.166 1413.26 3065.96 54.790 86.180 2325.29 2407.19 570.87 N 1377.64 E 5959948.93 N 600464.78 E 0.359 1488.44 . 3161.71 55.270 86.240 2380.17 2462.07 576.05 N 1455.93 E 5959955.15 N 600543.00 E 0.504 1564.15 3257.42 55.470 86.330 2434.56 2516.46 581.16 N 1534.52 E 5959961.29 N 600621.51 E 0.223 1640.12 3353.16 54.750 86.580 2489.33 2571.23 586.01 N 1612.90 E 5959967.18 N 600699.82 E 0.782 1715.81 3449.13 54.870 85.250 2544.63 2626.53 591.60 N 1691.13 E 5959973.80 N 600777.97 E 1.139 1791.60 3544.54 55.910 84.360 2598.82 2680.72 598.72 N 1769.33 E 5959981.94 N 600856.07 E 1.333 1867.86 3638.86 55.530 83.050 2651.95 2733.85 607.26 N 1846.79 E 5959991.51 N 600933.41 E 1.216 1943.88 3734.71 56.380 85.030 2705.62 2787.52 615.50 N 1925.78 E 5960000.79 N 601012.28 E 1.928 2021.24 3771.53 56.360 85.260 2726.01 2807.91 618.09 N 1956.33 E 5960003.78 N 601042.79 E 0.523 2050.97 3828.19 56.270 85.650 2757.43 2839.33 621.83 N 2003.32 E 5960008.14 N 601089.74 E 0.594 2096.63 3925.24 55.920 85.180 2811.57 2893.47 628.27 N 2083.61 E 5960015.64 N 601169.94 E 0.540 2174.64 4020.35 55.480 84.840 2865.17 2947.07 635.10 N 2161.89E 5960023.50 N 601248.11 E 0.549 2250.87 4116.30 54.500 84.570 2920.21 3002.11 642.35 N 2240.14 E 5960031.78 N 601326.26 E 1.047 2327.22 4212.21 55.730 85.950 2975.07 3056.97 648.84 N 2318.54 E 5960039.31 N 601404.57 E 1.743 2403.46 4308.01 55.190 85.430 3029.38 3111.28 654.77 N 2397.23 E 5960046.28 N 601483.18 E 0.719 2479.80 4403.63 54.440 86.030 3084.48 3166.38 660.59 N 2475.16 E 5960053.13 N 601561.02 E 0.937 2555.38 4499.08 55.900 88.560 3139.00 3220.90 664.28 N 2553.41 E 5960057.84 N 601639.22 E 2.659 2630.56 4594.49 55.070 87.810 3193.06 3274.96 666.76 N 2631.99 E 5960061.36 N 601717.75 E 1.085 2705.67 . 4690.66 54.500 88.060 3248.52 3330.42 669.60 N 2710.50 E 5960065.23 N 601796.23 E 0.630 2780.83 4786.06 55.440 87.470 3303.28 3385.18 672.64 N 2788.56 E 5960069.31 N 601874.24 E 1.108 2855.63 4881.13 56.620 85.960 3356.40 3438.30 677.17 N 2867.27 E 5960074.87 N 601952.88 E 1.810 2931.52 4977.08 58.440 83.690 3407.92 3489.82 684.49 N 2947.88 E 5960083.25 N 602033.39 E 2.753 3010.12 5072.96 59.780 79.950 3457.15 3539.05 696.21 N 3029.30 E 5960096.04 N 602114.64 E 3.627 3090.92 5168.60 60.730 74.540 3504.63 3586.53 714.55 N 3110.23E 5960115.45 N 602195.33 E 5.010 3173.42 5264.58 59.360 70.210 3552.57 3634.47 739.70 N 3189.47 E 5960141.64 N 602274.23 E 4.161 3256.52 5360.02 58.040 65.990 3602.17 3684.07 770.08 N 3265.11 E 5960173.02 N 602349.46 E 4.023 3337.94 5455.95 54.700 62.350 3655.30 3737.20 804.83 N 3337.00 E 5960208.71 N 602420.88 E 4.701 3417.22 5551.57 53.620 60.260 3711.29 3793.19 842.03 N 3404.99 E 5960246.81 N 602488.38 E 2.101 3493.62 5646.46 53.450 59.030 3767.69 3849.59 880.60 N 3470.84 E 5960286.24 N 602553.71 E 1.058 3568.44 5742.05 53.020 59.040 3824.90 3906.80 920.00 N 3536.50 E 5960326.50 N 602618.85 E 0.450 3643.35 9 November, 2004 - 10:59 Page 3 of 5 Dril/Quest 3.03.06.006 BP EXPLORA TION (ALASKA) INC. Survey Report for Z-21OPB1 (mwd) Your Ref: API 500292322670 Job No. AKMW3328880, Surveyed: 16 October, 2004 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 5838.37 52.720 59.020 3883.05 3964.95 959.51 N 3602.35 E 5960366.88 N 602684.17 E 0.312 3718.47 5934.01 54.420 58.870 3939.84 4021.74 999.21 N 3668.26 E 5960407.44 N 602749.56 E 1.782 3793.72 6030.12 56.340 57.470 3994.44 4076.34 1040.93 N 3735.45 E 5960450.04 N 602816.19 E 2.330 3870.83 6126.11 56.510 57.160 4047.53 4129.43 1084.12 N 3802.76 E 5960494.12 N 602882.93 E 0.322 3948.54 6221.90 57.110 57.420 4099.96 4181.86 1127.43 N 3870.21 E 5960538.32 N 602949.80 E 0.666 4026.41 6316.38 55.920 57.690 4152.09 4233.99 1169.71 N 3936.71 E 5960581 .4 7 N 603015.73 E 1.282 4103.05 . 6413.15 56.040 58.240 4206.23 4288.13 1212.25 N 4004.70 E 5960624.91 N 603083.16 E 0.487 4181.19 6508.19 55.490 57.300 4259.70 4341.60 1254.16 N 4071.17 E 5960667.68 N 603149.07 E 1.002 4257.68 6602.83 54.020 57.020 4314.31 4396.21 1296.07 N 4136.11 E 5960710.44 N 603213.45 E 1.572 4332.72 6699.71 54.040 56.940 4371.21 4453.11 1338.79 N 4201.85 E 5960754.03 N 603278.62 E 0.070 4408.80 6794.92 54.180 57.220 4427.03 4508.93 1380.71 N 4266.60 E 5960796.80 N 603342.81 E 0.280 4483.66 6891.57 54.080 57.260 4483.66 4565.56 1423.09 N 4332.46 E 5960840.05 N 603408.11 E 0.109 4559.74 6986.41 53.850 56.720 4539.45 4621.35 1464.87 N 4396.77 E 5960882.67 N 603471.87 E 0.520 4634.15 7081.83 53.690 58.030 4595.85 4677.75 1506.37 N 4461.60 E 5960925.02 N 603536.14 E 1.120 4708.95 7177.33 54.150 62.510 4652.11 4734.01 1544.62 N 4528.60 E 5960964.15 N 603602.62 E 3.821 4784.75 7273.03 55.580 67.460 4707.21 4789.11 1577.67 N 4599.49 E 5960998.14 N 603673.08 E 4.485 4862.54 7368.80 55.560 67.700 4761.36 4843.26 1607.80 N 4672.51 E 5961029.22 N 603745.70 E 0.208 4941 .40 7464.40 55.350 67.850 4815.57 4897.47 1637.58 N 4745.41 E 5961059.97 N 603818.19 E 0.255 5020.02 7560.09 54.980 68.230 4870.23 4952.13 1666.96 N 4818.25 E 5961090.30 N 603890.64 E 0.506 5098.45 7655.56 54.850 67.200 4925.10 5007.00 1696.58 N 4890.54 E 5961120.87 N 603962.53 E 0.893 5176.45 7751.39 54.690 67.150 4980.38 5062.28 1726.95 N 4962.69 E 5961152.19 N 604034.27 E 0.172 5254.55 7830.32 54.290 66.170 5026.23 5108.13 1752.40 N 5021.68 E 5961178.41 N 604092.92 E 1.131 5318.61 7900.00 54.290 66.170 5066.90 5148.80 1775.26 N 5073.43 E 5961201.95 N 604144.37 E 0.000 5374.99 Projected Survey . All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 71.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7900.00ft., The Bottom Hole Displacement is 5375.06ft., in the Direction of 70.714° (True). 9 November, 2004 - 10:59 Page 4 of 5 Dril/Quest 3.03.06.006 BP EXPLORA TION (ALASKA) INC. Survey Report for Z-210PB1 (mwd) Your Ref: API 500292322670 Job No. AKMW3328880, Surveyed: 16 October, 2004 North Slope Alaska BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 7900.00 5148.80 1775.26 N 5073.43 E Projected Survey . Survey too/prOgram for Z-210PB1 (mwd) From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 648.71 0.00 647.65 648.71 7900.00 647.65 BP High Accuracy Gyro - GYD-CT-DMS 5148.80 MWD Magnetic . 9 November, 2004 - 10:59 Page 5 of 5 DrillQuest 3.03.06.006 TREE '" , 4-1/16" SM FMC ~NOTES' ¡' Wf-LLHEAO = FMC GEN 5 . ACTUA TOR = Z-210 KB. ELEV = 80.70' BF. ELEV = -- KOP= Max Angle = 60 @ 2206' Datum MD = 11316' / Datum TVD = 4482'55 · ~ 2500' -14-1/2" X LANDING NIP, 10 = 3.813" I I 120" X 34" ,215.5#, A53 ffiW INSULATED H 114' · I 3237' --4-1/2"HESXNIP,ID=3.813" I ~ I ~ 19-5/8" CSG, 40#, L-80, 10 = 8.835" I 3811' I I · 6302' -- 41/2" HES X NIP, ID - 3813" , . 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 6313' I 6313' -14-1/2" X 3-112" XO, 10 = 2.960" I I GAS LIFT rvtANDRELS I ST MD I TVD DEV I TYÆ I VLV LATCHI PORT DATE I Minimum ID = 2.813" @ 6408' L I 6 6191 14499 43 I CA-KBG-2 I SO BEl< I 10/31/041 3-1/2" HES X NIPPLE WA TERFLOOD rvtANDRELS ST MD TVD DEV TYÆ VLV LATCH PORT DATE 5 6351 4616 42 CA-MMG-W DMY RK - 10/31/04 4 6380 4638 41 CA-MMG-W DMY RK - 10/31/04 3 6466 4704 39 CA-MMG-W DMY RK - 10/31/04 2 6494 4726 38 CA-MMG-W OMY RK - 10/31/04 1 6551 4771 36 CA-MMG-W DMY RK - 10/31/04 ~ 5768' H 7" rvtARKffi JT WI RA TAG I --i 6316' H 7" rvtARKER JT WI RA TAG I :8 "..., 6324' -1T' X 3-1/2" BAKffi PRM PROD PKR, ID = 2,870" I "-' · I 6408' -13-1/2" HES X NIP, ID = 2.813" I :8 I 6419' -- 7" X 3-1/2" BAKffi PRM PROD PKR, 10 = 2.870" , 2S I ÆRFORA TION SUMrvtARY REF LOG: 1-13-1/2" HES X NIP, 10 = 2.813" I · I 6513' ANGLEATTOPÆRF: 43 @ 6366' . Note: Refer to Production DB for historical perf data :8 6524' H 7" X 3-1/2" BAKffi PRM PROD PKR, ID = 2.870" , SIZE SPF INTERV A L Opn/Sqz DATE Q 5 6366 - 6400 0 10/31/04 5 6446 - 6480 0 10/31/04 · -13-112" HES X NIP, 10 = 2.813" I 5 6486 - 6500 0 10/31/04 I 6580' 5 6548 - 6576 0 10/31/04 :8 6590' 7" X 3-1/2" BAKffi PRM PROD PKR, ID = 2.870" 5 6618 - 6654 0 10/31/04 2S I I I I 6617' 3-1/2" HES X NIP, 10 = 2.813'" WI RHC PLUG I -13-1/2" HES X NIP. 10 = 2.813" I I I I 6628' 13-1/2" TBG, 9.3#, L-80, .0087 bpf, 10 = 2.992" I 6638' 6640 H 3-1/2" TBG TAIL WLEG I I H ELMO TT LOG NOT A V AILABLE I I PBTD 6867' I I 17" CSG. 26#, L-80. 10 = 6.276" I 6949' I r 18-3/4" INJECTOR rvtA INBORE H 6958'md I DATE REV BY COMMENTS DATE REV BY COMMENTS ORION 10/11/04 TS PROPOSED COM PLETION WELL: 2-210 11/29/04 JLM/TLP COMPLETION ÆRMfT No: 2041810 API No: 50-029-23226-00 SEC 19, T11 N, R12E, 4566' FSL & 3578' FEL BP Exploration (Alaska) . :J¡J''¡~ /8 f - ;,Àt:J'1-lI0- . 11/22/04 Schlurnberger NO. 3272 Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, 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 Job# Log Description CD BL Date Color Z-210 10912990 USIT (PDC) 10/30/04 1 1 V-210 10687711 USIT (PDC) 11/09/04 1 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 Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 :::e::~~¡hC~ Date Delivered: //þ ¡; f / ./ :. ~1T~1TŒ (ID~ . n LJùlL FRANK H. MURKOWSKJ, GOVERNOR AI/ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Z-210i BP Exploration (Alaska) Inc. Permit No: 204-181 Surface Location: 4566' NSL, 3578' WEL, SEC. 19, TIIN, RI2E, UM (Planned) Bottomhole Location: 4609' NSL, 426' EWL, SEC. 20, TIIN, RI2E, UM Dear Mr.Crane: Enclosed is the approved application for permit to drill the above referenced service well. In accordance with 20AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name Z-210i PH and API number 50-029-23226-70 from records, data and logs acquired for well Z-210i. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to itness any required test. Contact the Commission's petroleum field inspector at (907) 659-3 ager). BY ORDER OF THE COMMISSION DATED thisQ?,L day of September, 2004 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation w/o encl. 1a. Type of work aJ Drill o Redrill 11b. Current Well Class o EXPlora~ 0 DeVeIOJm~ D.~ ORe-Entry o Stratigraphic Test IBI Service AQ~\@H>iØJJ en[J . 2. Operator Name: 5. Bond: 181 Blanket o Single Well 11. Well ~ftutmrqeNumber: BP Exploration (Alaska) Inc. Bond No. 2S100302630-277 Z-210i ". 3. Address: 6. Proposed Depth: 12. Field I Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 6948 TVD 5117 Prudhoe Bay Field I Orion 4a. Location of Well (Governmental Section): 7. Property Designation: Schrader Bluff Surface: ADL 028262 4566' NSL, 3578' WEL, SEC. 19, T11N, R12E, UM (Planned) 13. Approximate Spud Date: Top of Productive Horizon: 8. Land Use Permit: ,/ 4727' NSL, 140' EWL, SEC. 20, T11 N, R12E, UM October 15, 2004 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 4609' NSL, 426' EWL, SEC. 20, T11N, R12E, UM 2560 10,250' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool Surface: x- 599095 y- 5959360 Zone- ASP4 (Height above GL):Plan 82.5 feet Z-15 is 1,780' away /' 16. Deviated Wells: Kickoff Depth: 300 feet 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Maximum Hole Angle: 56 dearees Downhole: 2220 Surface: 1724 ./ 113.'q~~i~gSi ~é"' ...... .~! i Tc ID .........,....I:K,A unl ,;:'·f i, . Hole CasinQ WeiQht Grade CouDlinQ LenQth MD TVD MD TVD (includinQ sta oe data) Driven 20" 166.4# X-56 Welded 80' 29' 29' 109' 109' 260 sx Arctic Set (ADDrox.) 12-114" 9-5/8" 40# K-55 I L-80 BTC 3788' 29' 29' 3817' 2833' 622 sx AS Lite, 376 sx Class 'G' ,. 8-3/4" 7" 26# L-80 BTC-M 6918' 29' 29' 6947' 5116' 300 sx Class 'G', ../ 19. PRESENT WELLGONDITIONSl.JMMARY(TobØcòmpétedJorR~!'ÌUANPR~~!1try OpêrªtiåO$) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): I Effective Depth MD (ft): ¡Effective Depth TVD (ft): Junk (measured): > .. I .....\.. ,.~ '..')i> , , ..... ..·,c·',··..» .,...'..'.:.y..... ·.···.··JVH...'.p;·.·r !;:>.....;.r'Y~.. ,:;.; I Conductor ~ 1. Inter Procillction Liner Perforation Depth MD (ft): IPerfOration Depth TVD (ft): 20. Attachments 181 Filing Fee, $100 o BOP Sketch 181 Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis 181 Property Plat o Diverter Sketch o Seabed Report 181 Drilling Fluid Program 181 20 MC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify th~~le foregoing is true and correct to the best of my knowledge. Contact Rob Tirpack, 564-4166 Printed Name La II Crane Title Senior Drilling Engineer Sianature (./~ /~ Phone 564-4089 Date Prepared By Name/Number: <¡-Iý-c "'. Terrie Hubble, 564-4628 ... '7f ,'.., ....~.....;.;>...j:>.. ..... .........;;.....,......... .';.,;,;'.',.....:. .. ......,:... .,...¡;.:;.:>.:..'.; Permit Tó..ØfiIl , J I API Number: 23'2..2.6 Permit Approval ,It I See cover letter for Number: 2¡"').;/ - / ç 50- o;:z... 1- Date: q/;+/ t? ( other requirements Conditions of Approval: Samples Required DYes ~No Mud Log Required D Yes ~No . Hydrogen Sulfide Measures D Yes ~ No . Dir,ectional Survey Requir~d ~Yes DNa Dthe' Tf d ße P~,4C"C . Wi "^ IT I C£ ,,,€.ct t <b.(, ~ I 0 ~ '''î<-<-{ "" d . . p" (¿< ( '1~ SS {k \¿¡ j , '" it eVI'I,,-t.. 1>,0 PEte t Ø,,"'t'tØ0-4-1 i ~ "1'PINtJ. ~ ~ I r-I t\1 !'J. I APPROVED BY Date 9~/ 10 q Þ- ,/ ADDroved BvT-A I () D .... THE COMMISSION Form 10-401 ReWd 06 ~04 ............... VI\~'-"tt1l' ,- Submit In Duplicate . STATE OF ALASKA . ALA~ OIL AND GAS CONSERVATION COMMISSf{E C E IVE D PERMIT TO DRILL 20 MC 25.005 SEP 1 S 2004 'w GI\- '111~/20C1 . Gr. Prudhoe Bay Z-210i Permit to Drill Well Plan SUmmary I Well Name: I Z-210i I Type of Well (producer or injector): 1 USH Injector I Surface Location: 4,566' FSL, 3,578' FEL, Sec. 19, T11N, R12E / (As Staked) X = 599,095 Y = 5,959,360 Z-21 0 Pilot Hole 5,246' FSL, 661' FEL, Sec. 19, T11 N, R12E Target 1: X = 602,000 Y = 5,960,080 Z = 3,385' TVDss Z-21 0 Pilot Hole 800' FSL, 4376' FEL, Sec. 17, T11 N, R12E Target 2 Top OA: X = 603,550 Y = 5,960,935 Z = 4,620' TVDss Z-210 Pilot Hole 1,046' FSL, 3,765' FEL, Sec. 17, T11N, R12E Target 3 BHL: X = 604,157 Y = 5,961,190 Z = 5,090' TVDss Z-210i Target 1 Top OA: 4,727' FSL, 5,139' FEL, Sec. 20, T11N, R12E X = 602,810 Y = 5,959,572 Z = 4,545' TVDss Z-210i Target 2 BHL: 4,609' FSL, 4,853' FEL, Sec. 20, T11 N, R12E .r X = 603,098 Y = 5,959,458 Z = 5,034' TVDss I AFE Number: 1 ORD5M3570 , ~ Nabors 7es II GL: I 54.0' II KB: 116.5 I 28.5' I Estimated Start Date: I October 15, 2004 I I Operating days to complete: Pilot hole TD: 7,916' MD Mainbore KOP: 3,957' MD Mainbore TD: 6,948' MD TVD: 5,173' TVD: 2,912' TVD: 5,117' ' Max Inc: 56° Inc: 55° Max Inc: 55° KBE: 82.5' KBE: 82.5' KBE: 82.5' / Well Design: USH Grassroots Schrader Injector with appraisal pilot hole. / 4-W' X 3-W' TCII Completion. The 0 sands will have a 4-%" X 3-%" TCII Completion in the Schrader Bluff. Current Well Information General Z-210 PB1 Distance to Nearest Property: -11,020' at top OA to the nearest PBU/KRU unit boundary Distance to Nearest Well in Pool: -2,025' from top of OA to Z-15 Z-210i Mainbore Distance to Nearest Property: -10,250' at top OA to the nearest PBU/KRU unit boundary Distance to Nearest Well in Pool: -1,780' from top of OA to Z-15 / API Number: Well Type: Current Status: BHP (PB1): BHP (Mainbore): BHT: 50-029- ???? Development - Orion Schradefliìjector New well, 20" conductor, dr' /en ¡ 2,220 psi @ 4,965' TVDs (8.6 'g EMW). Normal pressure gradient. 2,185 psi @ 4,885' TVDs 8. ppg EMW). Normal pressure gradient. 115°F @ 4,965' TVDss esti ated (from L-pad Temp Log) Permit to Drill 09/14/04 ./ Mechanical Condition Z-210i: Nabors 9ES: Conductor: Gr.~rudhoe Bay Z-210i Permit to Drill Cellar Box above MSL = 54.0' KB height = 28.5' 20" X 34", 215.5 Ibltt, A53 ERW set at 109' RKB - to be set 1A Mile Well bore Near Well bore Mechanical Integrity Summary: / No wells are within % mile radius of Z-210 PB1 or Z-210i No Wellbore Near Wellbore integrity issues. Target Estimates Estimated Reserves: 0.927 MMBO Materials Needed - (use PES stock when possible) Suñace Casing: Production Casing: L-80 Completion: 160' 3,657' 1 each 1 each 25 each 1 assembly 1 lot 9-%",40#, L-80 BTC Casing 9-%", 40#, K-55 BTC Casing 9-%", BTC Float Shoe and Float Collar 9-%",40#, BTC Type TAM Port Collar 9-%" x 12 W Bow Spring Centralizers FMC 11" 5m Gen 5 Wellhead System 9-%" casing pups 5', 10', 20'. 6,948' 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 W Rigid Straight Blade Centralizers 7" casing pups 5', 10', 20' 7" RA Tag 7" 26# L-80 BTC-M Casing Short Joint 6,300' 300' 3 each 2 each 6 each 1 each 1 each 1 each 4 each 1 each 4 W' 12.60 I bitt , L-80, TCII tubing 3 W' 9.30 Ibltt, L-80, TCII tubing Baker PRM Production Packer 7" X 3-W' Halliburton 4-%" X-Nipple (3.813" ID) Halliburton 3-W' X-Nipple (2.813" ID) 11" X 4- W' FMC tubing hanger 4-1/16", 5m Cameron Tree 4-%" x 1" KBG-2 GLM 3-%" x 1-%" MMG injection mandrels 3 W' RA Tag Surface and Anti-Collision Issues Suñace Shut-in Wells: Z-28 and Z-29 will require surface shut-in and well house removal in order to move over well Z-21 O. Z-27 and Z-30 should be evaluated before the rig move as to whether it will require wellhouse removal and shut in for the rig move. Z-31 should not require well 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. 2 Permit to Drill 09/14/04 ./ Close A roach Well List: Well Name Ctr-Ctr Distance Z-28 16.5' Z-29 16.5' Z-30A 52.6' Z-101 70.7' Z-31 88.2' Gr. Prudhoe Bay Z-21 Oi Permit to Drill Reference MD 541' 391' 427' 1,715' 471' Allowable Deviation 5.2' 8.4' 43.8' 30.4' 78.2' Pro ram: Surface Gyro will be needed (run to 1200' or as conditions dictate) MWD I GR None 8-%" Pilot Hole: MWD I GR I Res I Den I Neu I PWD All realtime with recorded 8-%" Mainbore: MWD I GR I Res I Den I Neu I PWD All realtime with recorded Cased Hole: USIT Bond Lo Funnel vis 250-300 200-250 200-250 Interval Pilot Hole Mainbore YP 23-30 23-30 C IT b· P 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 (LSND) PH: 9.0-9.5 <600 Chlorides PV API Filtrate MBT 12-18 4-6 < 20 12-18 4-6 < 20 asmQJ u mg rogram Hole Csgl WtlFt Grade Co')" Burst Collapse Length Top Bottom Size Tba O.D. / (psi) (psi) MD I TVDrkb MD I TVDrkb Driven* 20" 166.4# X-56 Welded 80' 29' / 29' 109' /109' 12-%" 9-%" 40# K-55 BTC 3,950 2,570 160' 29' / 29' 189' /189' 12- %" 9-%" 40# L-80 BTC 5,750 3,090 3,628' 189' / 189' 3,817' / 2,833' 8-%" 7" 26# L-80 BTC-M 7,240 5,410 6,918' 29' / 29' 6,947' / 5,116' Tubina 4 Y2" 12.60# L-80 TCII 8,430 7,500 6,296' 29' / 29' 6,325' / 4,598' Tubing 3 Y2" 9.30# L-80 TCII 10,160 10,530 290' 6,325' / 4,598' 6,615' /4,823' *Two attempts were made to drill and install an insulated conductor. Both attempts failed due the localized thaw bulb allowing the influx of water during drilling. The conductor has been driven into place. At the time of writing this permit, the As-Built drawings have yet to be generated. /" 3 Permit to Drill 09/14/04 . Gr., Prudhoe Bay Z-21 Oi Permit to Drill Formation Markers Z-21 0 PB1 (Based on Schlumberger wp03) Formation Tops MD TVD TVDss Pore psi EMW (ppg) Hydrocarbons SV6 1,125' 1,108' 1,025' 472 8.8 No SV5 1,975' 1,783' 1,700' 782 8.8 No Base Permatrost 2,198' 1,913' 1,830' 842 8.8 No SV4 2,216' 1,923' 1,840' 846 8.8 Poss. Gas Hydrates Fault 1 2,331' 1,988' 1,905' Fault Fault Fault SV3 2,636' 2,163' 2,080' 957 8.8 Poss. Gas Hydrates SV2 3,023' 2,383' 2,300' 1,058 8.8 Poss. Gas Hydrates SV1 3,640' 2,733' 2,650' 1,219 8.8 Poss. Gas Hydrates UG4 4,266' 3,088' 3,005' 1,382 8.8 Thin coal UG4A 4,345' 3,133' 3,050' 1,403 8.8 Heavy Oil between 3065' and 3200' ss UG3 4,936' 3,468' 3,385' 1,557 8.8 Thin coals/poss. Heavy oil UG1 5,863' 3,998' 3,915' 1,801 8.8 Heavy Oil between 4060' and 4205' ss Schrader Bluff/Ma Sand 6,374' 4,288' 4,205' 1,910 8.7 No Mb1 6,480' 4,348' 4,265' 1,940 8.7 No Mb2 6,568' 4,398' 4,315' 1,960 8.7 Heavy Oil between 4235' and 4300' ss Mc 6,692' 4,468' 4,385' 1,990 8.7 No Na 6,807' 4,533' 4,450' 2,015 8.7 No Nb 6,851' 4,558' 4,475' 2,030 8.7 No Nc 6,921' 4,598' 4,515' 2,050 8.7 No OA 7,107' 4,703' 4,620' 2,085 8.7 Yes OBa 7,212' 4,763' 4,680' 2,100 8.6 Yes OBb 7,264' 4,793' 4,710' 2,115 8.6 Yes OBc 7,341' 4,838' 4,755' 2,130 8.6 Yes OBd 7,444' 4,898' 4,815' 2,145 8.6 Yes OBe 7,556' 4,963' 4,880' 2,170 8.6 Yes OBt 7,616' 4,998' 4,915' 2,200 8.6 Yes OBt Base 7,702' 5,047' 4,965' 2,220 8.6 No T.D.* 7,916' 5,173' 5,090' r,O *TD is based on 125' TVD below the OBt base marker.* Formation Markers Z-210i (Based on Schlumberger wp07) Formation Tops MD TVD TVDss Pore psi EMW (ppg) Hydrocarbons KOP 3,957' 2,912' 2,830' 1,295 8.8 UG4 4,228' 3,083' 3,000' 1,380 8.8 Thin coal UG4A 4,302' 3,133' 3,050' 1 ,403 8.8 Heavy oil between 3060' and 3205' ss UG3 4,748' 3,453' 3,370' 1,550 8.8 Thin coallpossible heavy oil UG1 5,437' 3,953' 3,870' 1,780 8.8 Heavy oil between 4005' and 4130' ss Schrader Bluff/Ma Sand 5,794' 4,213' 4,130' 1,880 8.8 Water Mb1 5,870' 4,268' 4,185' 1,904 8.7 Water Mb2 5,946' 4,323' 4,240' 1,925 8.7 Water Mc 6,035' 4,388' 4,305' 1,950 8.7 Water Na 6,125' 4,453' 4,370' 1,980 8.7 Water Nb 6,159' 4,4 78' 4,395' 1,990 8.7 Water Nc 6,221' 4,523' 4,440' 2,010 8.7 Water OA 6,366' 4,628' 4,545' 2,025 8.6 Yes OBa 6,446' 4,688' 4,605' 2,050 8.6 Yes OBb 6,485' 4,718' 4,635' 2,065 8.6 Yes OBc 6,542' 4,763' 4,680' 2,085 8.6 Yes OBd 6,615' 4,823' 4,740' 2,110 8.6 Yes OBe 6,692' 4,888' 4,805' 2,140 8.6 Yes OBt 6,732' 4,923' 4,840' 2,155 8.6 Yes OBt Base 6,783' 4,968' 4,885' 2,175 8.6 Yes T.D.* 6,947' 5,116' 5,033' *TD is based on 150' TVD below the OBt base marker. * 4 Permit to Drill 09/14/04 e.: Gr. Prudhoe Bay Z-21 Oi Permit to Drill Cement Calculations Casin Size: 9-%-in 40-lb/ft K-55/L-80 BTC - Single Stage Basis: Lead: 250% ex ver gauge hole in permafrost, 30% excess over gauge hole below permafrost Lead TOC: rfac Tail: 1,000' eñ hole with 30% excess, plus 80' shoe track Tail TOC: 2,817' MD Total Cement Volume: Spacer Lead Tail Tem 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. Casin Basis: Central izer 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 2,817' 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 5,194' 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 BHA Hole Size Depths (MD) Bit Type Nozzles K-Revs Hours Number and Section Surface 12-%" 0' - 2,198' Hughes MXC-1 18/18/18/16 - - Surface 12- %" 2,198' - 3,816' Hughes MXC-1 18/18/18/16 - - PB1 8-% 3,817' -7,916' HvcaloQ DS70NPV 6x14 - - Mainbore 8-% 3,957' - 6,947' HvcaloQ DS70NPV 6x14 - - Flow Rate RPMs 400 - 700 gpm 60-80 3 500 - 600 gpm 60-120 5 Permit to Drill 09/14/04 .; Gr.prudhoe Bay Z-210i Permit to Drill 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. Due 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 Z-21 Oi 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: 2,220 psi - Base of Schrader (8.6 ppg @ 4,965' TVDss) 1,724 psi - Based on a full column of gas @ 0.10 psi/ft ,;' 4,000 psi/250 psi Rams 2,500 psi/250 psi Annular 4,000 psi LOT 20' from 9-5/8" shoe 50 bbls with an 11.4 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 II wastes to DS-04 for injection. Haul all Class I waste to Pad 3 for disposal. 6 Permit to Drill 09/14/04 e¡ Gr.prUdhoe Bay Z-210i Permit to Drill DrillinCl Hazards and Continqencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Schrader in the Polygon 3 fault block is expected to be normal pressured at 8.5-8.6 ppg EMW. This pressure is estimated based on offset well pressures and material balance. II. Hydrates and Shallow gas A. Gas Hydrates are expected at Z-pad near the base of the permafrost. 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. Occasionally hydrates are encountered below the SV1. III. Lost Circulation/Breathing A. Lost circulation is not expected at the Z-Pad fault. In addition the fault will be crossed at high angle and move away quickly. 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 15.8Ib/gal tail cement to 600' MD above the Ma sand -5,194' MD. C. The Kick Tolerance for the surface casing is 50 bbls with 9.3 ppg mud, 11.4 ppg LOT, and an 8.8 ppg pore pressure. D. Integrity Testing - LOT to a minimum of 11.4 ppg EMW. V. Stuck Pipe A. We do not expect stuck pipe if the hole is kept adequately clean. VI. Hydrogen Sulfide Z Pad is..!J.Qtdesignated 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 Z pad as a result of the use of Ivishak gas lift gas. All Z pad gas lift wells will likely have H2S in this concentration. Note that all injection has been with produced water not seawater. H2S levels are expected to remain low until the waterflood matures. Recent H2S data from the pad is as follows: Adjacent producers at Surface: Adjacent producers at TO: Z-29 10 ppm Z-13 10 ppm Z-16 10 ppm Max Recorded on Z-Pad: Z-35 - 20 ppm VII. Faults A. One fault is expected to be crossed at Z-21 Oi. No losses are expected to be associated with this fault. Details are listed below for reference: Fault 1 (SV4): 2,331' MD 1,998' TVD 1,905' TVDss Throw: 155' SW CONSULT THE V PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 7 Permit to Drill 09/14/04 _ . Gr.prUdhoe Bay Z-210i Permit to Drill Dri/l and Complete Procedure Summary Pre-Rig Work: 1. The Z-21 Oi conductor has been driven into place. 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 Z-28 and Z-29 and remove well houses as necessary. t"" Rig Operations: 1. MIRU Nabors ges. ./ 2. Nipple up diverter spool and function test diverter. PU 4" DP as required and stand back in derrick. 3. MU 12-%" drilling assembly with MWD/GR and directionally drill surface hole to approximately 3,817' MD. The __ actual surface hole TD will be +/-100' TVD below the top of the SV1 sands. 4. Run and cement the 9-%", 40.0-lb/ft L-80/K-55 surface casing back to surface. A TAM port collar 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 / tubing head. NU BOPE and test to 4,000 psi. ~ 6. MU 8-3,4" 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 9.0 ppg mud 8. Drill new formation to 20' below 9-%" shoe and perform LOT (If a 11.4 ppg EMW is not obtained contact ODE). 9. Drill ahead to Polygon 3 pilot hole TD at 7,916' MD, (125' TVD below base OBf marker). ,,/ 10. Condition the hole for P&A plug. POOH to LD drilling BHA, standing back the 4" DP. 11. RIH w/3 1/2" cement stinger and plug catching sub on 4" DP to TD, spot a 900' balanced 15.8 ppg Class G { cement abandonment plug from TD to 7,016' MD. 12. Circulate out drill pipe and cement. Spot second 900' balance 15.8 ppg Class G cement abandonment plug from 7,016' MD to 6,116' MD (258' above Schrader Ma sand). 13. POOH to 3 stands above plug, circulate out drill pipe and contaminated mud, POOH. ..-/ 14. MU 8-%" drilling assembly with MWD/GR/Res/Den/Neu(recorded)/PWD and RIH reaming and washing to top of cement plug. Place "sufficient weight on the plug to confirm its location and to confirm that the plug has set / and a comp' en plug is in place" (AOGCC). 15. POOH t 3,95 MD and lowside existing wellbore to continue with drilling the Polygon 3 Schrader injection ./~ mainbor III ahead to 6,948' MD (base of OBf target plus 150' TVD). 16. Circulate and condition hole, make a short trip, TOOH to run casing. 17. Run and cement the 7" production casing as required to cover all significant hydrocarbon intervals. Displace ./ the casing with seawater during cementing operations. Pressure test casing to 4,000 psi for 30 minutes at plug bump. Freeze protect the 7" x 9-%" annulus. 18. PU DPC guns and RIH w/ -190' of 4.5" Power Jet 5 spf perf guns (total assembly length to be -350') with / Schlumberger LWD GR. Tag PBTD. 19. Circ hole over to 9.0 ppg brine. 20. Space out utilizing GR and RA tags in 7" casing with LWD. Once spaced out correctly, confirm cement compressive strength is at least 2,000 psi. Perforate OA, OBa, OBb, and OBd. ./ 21. RU Schlumberger E-line. RIH with gage ring and junk basket to recover any perf debris. Repeat until clean. 22. Run USIT/GR log. USIT will be primary depth control for future well work. ./' 23. Run the 4-W' X 3-%", L-80 TCII completion with a 7" x 3-%" straddle packer assembly and injection mandrels. ./ 24. 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. 25. Install FMC TWC. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. 26. Freeze protect the well to -2,500' TVD. Install BPV in tubing hanger. Install a VR plug in the 7"x 4-W' annulus / valve and secure the well. Assure that IAlOA are both protected with two barriers. 27. Rig down and move off. 8 Permit to Drill 09/14/04 . Gr. Prudhoe Bay Z-210i Permit to Drill Post-Rig Work: 1. R/U Slickline and pull ball and rod / RHC from the tailpipe. / 2. Replace the DCK shear valve with a dummy GLV. 3. Pull dummy valves in injection mandrels and replace with injection valves. 4. Pull VR plug. 9 Permit to Drill 09/14/04 · GraPrUdhoe Bay Z-210i Permit to Drill Z-210i 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. ~ Z-28 and Z-29 will have to be shut in and require well house 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. ~ Z 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 Z pad as a result of the use of Ivishak gas lift gas. All Z 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: Z-29 Z-16 10 ppm 10 ppm Adjacent producers at TD: Z-13 10 ppm Max Recorded on Z-Pad: Z-35 - 20 ppm Reference SOP .:. "Drilling/ Work over Close Proximity Surface and Subsurface Wells Procedure" Job 2: Drill 12%" Surface Hole Critical Issues: ~ At Z-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 Z-28 and Z-29 are required to be shut in and have their wellhouses removed due to surface location proximity to the Z-210i. 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 suñace hole, so as to minimize the chance for hole irregularity or obstructions that could cause problems while running casing. 10 Permit to Drill 09/14/04 . GrerprUdhoe Bay Z-210i 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 80-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 observed, 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. ~ Faults: One fault is expected to be crossed at Z-210i. No losses are expected to be associated with this fault. Details are listed below for reference: Fault 1 (SV4): 2,331' MD 1,998' TVD 1,905' TVDss Throw: 155' SW Reference RPs: .:. "Prudhoe Bay Directional Guidelines" .:. "Well 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 (8.835" ID, 8.75" drift). Ensure that casing equipment is properly drifted to ensure adequate ID for the 8-3,4" bit, i.e. float equipment, casing hanger, etc. ~ Cement to surface: A single-stage job will be done on this well using 250% excess in the permafrost and 30% excess below the permafrost. A TAM Port collar will be placed at 1,000-ft MD as a contingency. ~ Losses during cement job: Lost circulation has been experienced on offset pads 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-lb/gal EMW. Follow the Schlumberger recommended pumping rates as they have modeled the expected ECD's during the entire cement job to help mitigate the potential for breaking down the formations. Reference RPs .:. "Casing and Liner Running Procedure" .:. "Surface Casing and Cementing Guidelines" .:. "Surface Casing Port Collar Procedure" 11 Permit to Drill 09/14/04 . Gr. Prudhoe Bay Z-21 OJ Permit to Drill Job 4: Drill 8-% II Pilot Hole and Mainbore 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 T (minimum 11.4 ppg EMW to satisfy kick tolerance). KICK TOLERANCE: Based upon the m expe ted Schrader reservoir pressure of 8.8 ppg and 9.3 ppg mud, a 11.4 ppg leak-off will provi 50 b of kick tolerance. Contact Anchorage personnel if LOT is less than 11.4 ppg. Based up -set drilling data, 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 EGDs not to exceed 0.6ppg above calculated. If EGDs are sustained above this threshold, it is advised that drilling should be stopped and the hole circulated before continuing. EGD 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 OBf and OBd sands using the Gamma Ray. Therefore if the GR tool is lost, a trip will have to be made to change it out. ~ 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 BHA to minimize inclination walking tendencies thus minimizing wellbore tortuousity. DLS should be kept as close as possible to :<:;;10 over planned. Dogleg will take priority over angle as long as mainbore tangent angle does not approach 68 degrees. ~ 7" casing landing point: The 7" casing setting point will be determined by depth based on changes in GR/Res curves associated with the base OBf sand. After seeing the base OBf, TD will be picked based on drilling 150' TVD past this base. 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. ~ 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. .:. "ERD Operating Practices" 12 Permit to Drill 09/14/04 . Job 5: Plug 8 3A" Interval Gr.r Prudhoe Bay Z-21 OJ Permit to Drill Critical Issues ~ AOGCC: Notify AOGCC of intent to plug and abandon pilot hole at least 24 hours before pumping cement to allow enough time for them to witness the job. ~ Cement Job: It is imperative to achieve a good cement job to isolate the hydrocarbons drilled in the pilot hole from those to be drilled in the mainbore. The cement plug will be tagged to assure that it was placed correctly before the mainbore can be kicked off. ~ Plugging Pilot Hole: A 3 1/2" cement stinger and plug catching sub should be used to facilitate cement placement. This should allow for less mud contamination of the plug and lower the impact of sticking pipe while cementing. The hole should be circulated until returns are free of cement and cement contaminated mud after pulling above the final cement plug. This should assure a quicker dress off and set down for plug confirmation. ~ Cement Contamination: Mud contamination with cement was a problem on the L-210i when attempting to drill mainbore resulting in blinding of shakers. Treat mud and add lubricants as per MI procedures. ~ POOH: All operations should be arranged so that no delay will take place between setting the cement plug and POOH so as to assure that the pipe is pulled cleanly. Reference RPs .:. Setting a Kick-off or Abandonment Plug in Open Hole' RP for additional details Job 6: Run and Cement 7" 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 Ml'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. 13 Permit to Drill 09/14/04 · Gr.r Prudhoe Bay Z-210i Permit to Drill ~ 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 .:. "Intermediate Casing and Cementing Guidelines" .:. "Freeze Protecting an Outer Annulus" Job 7: DPC Perforate Well Critical Issues ~ Barriers: A wireline BOP with double downward rams should be used in conjunction with a packott 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" .:. "Alaska Wells Group Standard Operating Procedure: Perforating" .:. Follow Schlumberger perforating practices and recommendations Job 8: Run 4-%" Completion Critical Issues ~ Barriers: o The well will have the OA, OBa, 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 14 Permit to Drill 09/14/04 · Gr.r Prudhoe Bay Z-21 Oi Permit to Drill 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. 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. þ> 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. þ> 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/NUlRelease Rig Critical Issues þ> 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. þ> 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 15 Permit to Drill 09/14/04 seal bore. with 38· 37. 35. 34. 10 . 9 . 8 . 7 . 6 . 5 . 4 . 3 . 2 . 1 . 39 . 11 . 12 . 13 . 14 . 15 . 16 . 17 . 18. 19 . 20. l', · 33 · 32 · 31 · 30 Z-210i I 29 28 · 27 · P-504A · P-504B z -PAD · · · · · · 21 41 · 21 22 23 24 25 26 Slot 1 Z-1QO Z-101 , I ,(J¿ .(J(J Û)(J -~ I GRID :!! '" '" 111N VICINITY MAP N.T.S. LEGEND . AS-STAKED WELL CONDUCTOR . EXISTING WELL CONDUCTOR WELL Z-210i NOTE WELL Z-210i HAS BEEN MOVED FROM IT'S ORIGINAL LOCATION BETWEEN WELLS Z-29 AND Z-30. SOUTH 35 FEET AND IS NOW U~~S. ~~~8';:.. ~ NOTES 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4. NAD-27. 2. PAD AVERAGE SCALE FACTOR IS 0.999911213. 3. HORIZONTAL CONTROL IS BASED ON Z PAD CONTROL MONUMENTS MON 2 AND MON 3. 4. ELEVATIONS ARE BPX MEAN SEA LEVEL (M.S.L.) DATUM. 5. VERTICAL CONTROL IS BASED ON Z PAD MONUMENTATION. 6. REFERENCE FIELD BOOK: W004-13 PGS. 41-42. 7. DATE OF SURVEY: AUGUST 27, 2004. LOCATED WITHIN PROTRACTED SEC. 19. T. 11 N., R. 12 E., UMIAT MERIDIAN, ALASKA WELL ASP. PLANT GEODETIC GEODETIC GRAVEL SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) PAD ELEV. OFFSETS 210i Y=5,959,359.98 N= 2,210.00 70'17'54.287" 70.2984131' 52.5' 4,566' FSL x= 599,095.02 E= 2,130.00 149'11'50.946" 149.1974850' 3,578' FEL o 8 28 04 ISSUED FOR INFORMATION NO. DATE REVISION JJ RFA BY CHK ENGINEERS AND LAND SIJR'ÆYORS eD1W£$T FIIEWŒD \.NO[ ANCHa'tAGE. AI.ASI<¡\ 99503 DRAWN: ObP JACOBS CHECKED: ALLISON DATE: 6/26/04 DRAWING: FRB04 WOA-Z 06-00 JOB NO: SHEET: GPB WOA Z-PAD AS-STAKED CONDUCTOR WELL Z-21Oi 1 OF 1 SCALE: 1"=200' (Platt Z-2ìO/P1an Z-21O PBI Drtte; Plan: 2-210 PBI Created By: Troy Jaka!.msky Cb:e_-cked: Tool CB..oYRO-SS MWD SURVEY PROGRAM REFERENCE fNFORfl.iA. TION Shape tOO) Target Z-2WPEI T! Z-2JO PEl T2 Z-21O PEl Z-2HjpE11 CASING OET AILS TVD MO Name Size 2832.50 3816.59 9 9.625 - - - 210 7i ;¡:¡ '=' '=' t;. :t ~ ~ '" ~ '" 701 149"11'50.946W Easting 7(f'!754187N TARGET DETAILS +Ei-W Basting 599095.00 Northing Nooffimg 5959360;(10 ;·E/·W +Ni-S TVD PlanZ-2!O Tl T2 T3 Name 00.00 1636 FORMATION TOP DETAILS Formation MOPath TVDPath VSee TFace GLeg SECTION DETAILS +Ni-S O.t 0,( 1 1 1 TVD Azi lno 0.1 0.1 MD 21 30( 4{){ See 1 2 3 4 5 6 7 8 9 10 II 12 ,) ,2 No. 1 2 3 4 5 6 7 8 9 10 It 12 13 14 o '{'it.:.. COMPANY DETAILS REFFJtENCE INFORMATION m BP Amoco . Depth Pm Depth To Creared By; Troy Jakabosky 12¡){\.OO Checked; OiIte: ".W 791636 Reviewed; Date; WElt DETAILS CASING DETAILS N..", Nmhi"" """'" Latll:ude Loogitude SIo' No. TVD MD Name Size PìanZ·21O ·2!1U.!! 5959360.00 599095ßO NiA I 2832.50 3816.59 9518" 9.625 TARGET DETAILS Name TVD +NI·S +EI·W Northing Easting Shape ip~. ,I T! ~,?in,t T2 5960935.Ol 1(0) I T3 ¡"'Wi, i 1+ SECTION DETAILS ~ I , MD Ine TVD +EI·W DLe¡¡ TFace VSoc Target 1 0.' II) : ~: il.! ! 1 ,6' . . i 5 ~' 6 JOO '11 i. ' I. 7 ~ ¡ /. 9 \ 8 ~ ·9' Z·21O PBI TI 9 ~1 \; . , 10 :¡ Z·21O PBI T2 II ~~ .~' ~. 9' 1 \W' ':f ~'" 12 I~ Z-21O PBI T3 )() "~ 1 I ! . : :: .. ..... ""'T 1 f T ····1· T i --r ! . : ~ , i . :¡¡ j 1 ¡ i i Ii I .. I ¢: + I . . . , '..... .. . Q Q Ë T . m ¡ ': i . Q . . i . 'j "1 "3 i5í! ii .1 . . T . i .f: i ~ , .. ~ 300 Ji.. tl ! ...... i : .~¡.,;;;;; ;;¡;;, . 50\) . 1 i- : ' : ....i. ",IT> ': . i 4 i i ¡ i . ,~ /' '-" ~ '/ 500 "ßj ;; : I 'P i i ! 0 1000 2000 3000 4000 5000 6000 7000 8000 Vertical Soction at 70.88' [IOOOfifinj . . BP BP Planning Report Plan: Z-210 PB1 wp03 Date Composed: Version: Tied-to: 6/15/2004 8 From Well Ref. Point Company: Field: Site: Well: Wellpath: BPAmoco Prudhoe Bay PB Z Pad Plan Z-210 Plan Z-210 PB1 Seetion Principal: Yes Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: PB Z Pad TR-11-12 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5957230.17 ft 601304.82 ft Latitude: 70 17 Longitude: 149 10 North Reference: Grid Convergence: 33.051 N 47.365 W True 0.77 deg Well: Plan Z-210 Slot Name: Well Position: +N/-S 2159.61 ft Northing: 5959360.00 ft Latitude: 70 17 54.287 N +E/-W -2181.11 ft Easting : 599095.00 ft Longitude: 149 11 50.946 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 3816.59 2832.50 9.625 12.250 95/8" Formations MD TVD Fonnadons J,ithology ft ft 1124.89 1107.50 SV6 0.00 0.00 1975.31 1782.50 SV5 0.00 0.00 2198.49 1912.50 Base Permafrost 0.00 0.00 2216.14 1922.50 SV4 0.00 0.00 2330.77 1987.50 Fault #1 0.00 0.00 2636.23 2162.50 SV3 0.00 0.00 3023.48 2382.50 SV2 0.00 0.00 3640.35 2732.50 SV1 0.00 0.00 4266.02 3087.50 UG4 0.00 0.00 4345.33 3132.50 UG4A 0.00 0.00 4935.75 3467.50 UG3 0.00 0.00 5862.72 3997.50 UG1 0.00 0.00 6374.37 4287.50 Ma 0.00 0.00 6480.23 4347.50 Mb1 0.00 0.00 6568.44 4397.50 Mb2 0.00 0.00 6691.95 4467.50 Me 0.00 0.00 6806.63 4532.50 Na 0.00 0.00 6850.73 4557.50 Nb 0.00 0.00 6921.31 4597.50 Nc 0.00 0.00 7106.56 4702.50 OA 0.00 0.00 7211.55 4762.50 OBa 0.00 0.00 7263.52 4792.50 OBb 0.00 0.00 7341.01 4837.50 OBc 0.00 0.00 7444.06 4897.50 OBd 0.00 0.00 7555.69 4962.50 OBe 0.00 0.00 7615.81 4997.50 OBf 0.00 0.00 7701.68 5047.50 OBCBase 0.00 0.00 Company: Field: Site: Well: WeUpath: Targets . . BP BP Planning Report BP Amoco Prudhoe Bay PB Z Pad Plan Z-210 Plan Z-210 PB1 Date: 8/2512004 Co-ordinate(NE) Referenee: Vertieal (TVD) Referenee: Section (VS) Referenee: Snrvey Calenlation Method: f)eseriptlon Dip. Dir. TVD ft 3467.50 681.70 2914.50 5960080.00 602000.00 70 18 0.986 N 149 10 25.979 W 4702.50 1516.26 4475.77 5960935.01 603549.99 70 18 9.186 N 149 9 40.443 W 5172.50 1763.26 5086.14 5961190.01 604156.99 70 18 11.612 N 149 9 22.647 W Z-210 PB1 T1 -Plan hit target Z-210 PB1 T2 -Circle (Radius: 100) -Plan hit target Z-210 PB1 T3 -Circle (Radius: 200) -Plan hit target Plan Section Information ft 28.50 300.00 400.00 741.07 2096.32 2282.35 2738.75 4935.75 5509.87 7106.56 7341.27 7916.36 Survey MD 28.50 50.00 75.00 100.00 125.00 150.00 175.00 200.00 225.00 250.00 275.00 300.00 325.00 350.00 375.00 400.00 425.00 450.00 475.00 500.00 525.00 550.00 575.00 600.00 625.00 650.00 675.00 700.00 Inel Azim TVD +N/-S +FJ..W DLS~dTnJ'D TFO deg deg ft ft déWWOft degtl()Oft degt1 ()Oft de9 0.00 0.00 28.50 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 1.50 20.00 399.99 1.23 0.45 1.50 1.50 0.00 20.00 10.00 30.00 739.03 31.13 16.81 2.50 2.49 2.93 11.73 55.50 64.00 1854.63 399.10 611.96 3.50 3.36 2.51 38.74 55.50 64.00 1960.00 466.31 749.76 0.00 0.00 0.00 0.00 55.43 86.21 2220.95 561.99 1109.34 4.00 -0.01 4.87 96.56 55.43 86.21 3467.50 681.70 2914.50 0.00 0.00 0.00 0.00 55.47 58.23 3797.50 823.74 3357.37 4.00 0.01 -4.87 -97.94 55.47 58.23 4702.50 1516.26 4475.77 0.00 0.00 0.00 0.00 54.39 69.64 4837.65 1600.55 4647.81 4.00 -0.46 4.86 99.88 54.39 69.64 5172.50 1763.26 5086.14 0.00 0.00 0.00 0.00 Target Z-210 PB1 T1 Z-210 PB1 T2 Z-210 PB1 T3 Inel AziQl TVD S15 TVD N/S EIW DLS ~pN deg deg ft ft ft ft deg/1 ()Oft ft 0.00 0.00 28.50 -54.00 0.00 0.00 0.00 5959360.00 CB-GYRO-SS 0.00 0.00 50.00 -32.50 0.00 0.00 0.00 5959360.00 CB-GYRO-SS 0.00 0.00 75.00 -7.50 0.00 0.00 0.00 5959360.00 CB-GYRO-SS 0.00 0.00 100.00 17.50 0.00 0.00 0.00 5959360.00 CB-GYRO-SS 0.00 0.00 125.00 42.50 0.00 0.00 0.00 5959360.00 CB-GYRO-SS 0.00 0.00 150.00 67.50 0.00 0.00 0.00 5959360.00 599095.00 CB-GYRO-SS 0.00 0.00 175.00 92.50 0.00 0.00 0.00 5959360.00 599095.00 CB-GYRO-SS 0.00 0.00 200.00 117.50 0.00 0.00 0.00 5959360.00 599095.00 CB-GYRO-SS 0.00 0.00 225.00 142.50 0.00 0.00 0.00 5959360.00 599095.00 CB-GYRO-SS 0.00 0.00 250.00 167.50 0.00 0.00 0.00 5959360.00 599095.00 CB-GYRO-SS 0.00 0.00 275.00 192.50 0.00 0.00 0.00 5959360.00 599095.00 CB-GYRO-SS 0.00 0.00 300.00 217.50 0.00 0.00 0.00 5959360.00 599095.00 Start Dir 1.5/1 0.38 20.00 325.00 242.50 0.08 0.03 1.50 5959360.08 599095.03 CB-GYRO-SS 0.75 20.00 350.00 267.50 0.31 0.11 1.50 5959360.31 599095.11 CB-GYRO-c;S 1.13 20.00 375.00 292.50 0.69 0.25 1.50 5959360.70 599095.24 CB-GYRO-SS 1.50 20.00 399.99 317.49 1.23 0.45 1.50 5959361.24 599095.43 Start Dir 2.5/1 2.12 23.44 424.98 342.48 1.96 0.74 2.50 5959361.97 599095.72 CB-GYRO-SS 2.74 25.33 449.95 367.45 2.92 1.18 2.50 5959362.94 599096.14 CB-GYRO-SS 3.36 26.52 474.92 392.42 4.12 1.76 2.50 5959364.14 599096.71 CB-GYRQ-SS 3.98 27.34 499.87 417.37 5.54 2.49 2.50 5959365.58 599097.42 CB-GYRO-SS 4.60 27.94 524.80 442.30 7.20 3.36 2.50 5959367.24 599098.26 CB-GYRO-SS 5.23 28.39 549.70 467.20 9.09 4.37 2.50 5959369.14 599099.25 CB-GYRO-SS 5.85 28.75 574.59 492.09 11.21 5.52 2.50 5959371.28 599100.38 CB-GYRO-SS 6.48 29.04 599.44 516.94 13.56 6.82 2.50 5959373.65 599101.64 CB-GYRO-SS 7.10 29.28 624.27 541.77 16.14 8.26 2.50 5959376.24 599103.05 CB-GYRQ-SS 7.72 29.48 649.06 566.56 18.95 9.84 2.50 5959379.07 599104.59 CB-GYRO-SS 8.35 29.65 673.81 591.31 21.99 11.57 2.50 5959382.14 599106.28 CB-GYRO-SS 8.97 29.80 698.53 616.03 25.26 13.44 2.50 5959385.43 599108.10 CB-GYRO-SS . . BP BP Planning Report Company: BPAmoco Date. 81251~.. .. ...('J'i.:((15:4~:31 . . .i;Ši..ap: 3 Field: Pru<fhoeBay Co-ordinat~)Referenee: wen.: ptaf\¡!-210.:~Nô!'ttJ Site: PB Z Pad Vertical (TVD) Reference: 54+:28.582.5 WeD. Plan Z-210 SeetlolI{VS) Refereaee: WElfl(O.OON.0;O()E.7Q,88~) Wellpath: Plan Z-210 PB1 Survey Caleulatiø.Method: Mlnimum·Curvafure Db: OraCle Survey MD Iael Azim TVD Sys TVD N/S EIW DLS MapN i;~0 ft deg deg ft ft ft ft deg/10Oft ft 725.00 9.60 29.93 723.20 640.70 28.76 15.45 2.50 5959388.95 599110.06 CB-GYRO-SS 741.07 10.00 30.00 739.03 656.53 31.13 16.81 2.50 5959391.34 599111.40 Start Dir 3.5/1 750.00 10.25 31.10 747.83 665.33 32.48 17.61 3.50 5959392.70 599112.18 CB-GYRO-SS 775.00 10.95 33.91 772.40 689.90 36.35 20.08 3.50 5959396.61 599114.60 CB-GYRO-SS 800.00 11.68 36.39 796.91 714.41 40.36 22.91 3.50 5959400.65 599117 .37 CB-GYRO-SS 825.00 12.43 38.57 821.36 738.86 44.50 26.09 3.50 5959404.84 599120.50 CB-GYRO-SS 850.00 13.19 40.51 845.74 763.24 48.77 29.62 3.50 5959409.15 599123.97 CB-GYRO-SS 875.00 13.96 42.23 870.04 787.54 53.17 33.50 3.50 5959413.61 599127.79 CB-GYRO-SS 900.00 14.75 43.78 894.26 811.76 57.71 37.73 3.50 5959418.19 599131.96 CB-GYRO-SS 925.00 15.55 45.17 918.39 835.89 62.37 42.31 3.50 5959422.91 599136.48 CB-GYRO-SS 950.00 16.35 46.43 942.43 859.93 67.15 47.23 3.50 5959427.76 599141.34 CB-GYRO-SS 975.00 17.16 47.58 966.37 883.87 72.07 52.50 3.50 5959432.75 599146.54 CB-GYRO-SS 1000.00 17.98 48.62 990.20 907.70 77.10 58.12 3.50 5959437.86 599152.09 CB-GYRO-SS 1025.00 18.80 49.58 1013.93 931.43 82.27 64.08 3.50 5959443.10 599157.99 CB-GYRO-jS 1050.00 19.62 50.46 1037.53 955.03 87.55 70.39 3.50 5959448.46 599164.22 CB-GYRO-SS 1075.00 20.45 51.27 1061.02 978.52 92.96 77.03 3.50 5959453.96 599170.79 CB-GYRO-SS 1100.00 21.29 52.02 1084.38 1001.88 98.48 84.02 3.50 5959459.57 599177.70 CB-GYRO-SS 1124.89 22.12 52.71 1107.50 1025.00 104.10 91.31 3.50 5959465.29 599184.92 SV6 1125.00 22.12 52.71 1107.61 1025.11 104.13 91.34 3.50 5959465.31 599184.95 CB-GYRO-SS 1150.00 22.96 53.36 1130.69 1048.19 109.89 99.00 3.50 5959471.18 599192.53 CB-GYRO-SS 1175.00 23.80 53.96 1153.64 1071.14 115.77 106.99 3.50 5959477.16 599200.45 CB-GYRO-SS 1200.00 24.65 54.53 1176.44 1093.94 121.76 115.32 3.50 5959483.26 599208.69 MWD 1225.00 25.49 55.06 1199.08 1116.58 127.87 123.97 3.50 5959489.48 599217.27 MWD 1250.00 26.34 55.55 1221.57 1139.07 134.09 132.96 3.50 5959495.82 599226.17 MWD 1275.00 27.19 56.02 1243.89 1161.39 140.42 142.27 3.50 5959502.27 599235.39 MWD 1300.00 28.04 56.47 1266.04 1183.54 146.86 151.90 3.50 5959508.83 599244.94 MWD 1325.00 28.89 56.88 1288.02 1205.52 153.40 161.86 3.50 5959515.51 599254.81 MWD 1350.00 29.75 57.28 1309.82 1227.32 160.06 172.14 3.50 5959522.30 599265.00 MWD 1375.00 30.60 57.66 1331.43 1248.93 166.81 182.73 3.50 5959529.19 599275.50 MWD 1400.00 31.46 58.02 1352.85 1270.35 173.67 193.64 3.50 5959536.19 599286.32 MWD 1425.00 32.31 58.36 1374.08 1291.58 180.63 204.86 3.50 5959543.30 599297.45 MWD 1450.00 33.17 58.68 1395.11 1312.61 187.69 216.39 3.50 5959550.51 599308.88 MWD 1475.00 34.03 58.99 1415.93 1333.43 194.85 228.23 3.50 5959557.83 599320.62 MWD 1500.00 34.89 59.29 1436.54 1354.04 202.11 240.37 3.50 5959565.24 599332.67 MWD 1525.00 35.75 59.57 1456.94 1374.44 209.46 252.82 3.50 5959572.75 599345.01 MWD 1550.00 36.61 59.85 1477.12 1394.62 216.90 265.56 3.50 5959580.36 599357.65 MWD 1575.00 37.47 60.11 1497.08 1414.58 224.43 278.60 3.50 5959588.07 599370.59 MWD 1600.00 38.33 60.36 1516.81 1434.31 232.05 291.93 3.50 5959595.86 599383.82 MWD 1625.00 39.19 60.60 1536.30 1453.80 239.77 305.55 3.50 5959603.75 599397.33 MWD 1650.00 40.05 60.84 1555.56 1473.06 247.56 319.45 3.50 5959611.73 599411.13 MWD 1675.00 40.91 61.06 1574.57 1492.07 255.44 333.64 3.50 5959619.80 599425.22 MWD 1700.00 41.78 61.28 1593.34 1510.84 263.41 348.11 3.50 5959627.95 599439.58 MWD 1725.00 42.64 61.49 1611.86 1529.36 271.45 362.86 3.50 5959636.19 599454.21 MWD 1750.00 43.50 61.70 1630.12 1547.62 279.57 377 .87 3.50 5959644.50 599469.12 MWD 1775.00 44.37 61.89 1648.12 1565.62 287.77 393.16 3.50 5959652.90 599484.30 MWD 1800.00 45.23 62.08 1665.86 1583.36 296.04 408.71 3.50 5959661.38 599499.74 MWD 1825.00 46.10 62.27 1683.33 1600.83 304.39 424.53 3.50 5959669.93 599515.44 MWD 1850.00 46.96 62.45 1700.53 1618.03 312.81 440.60 3.50 5959678.56 599531.40 MWD 1875.00 47.83 62.63 1717.45 1634.95 321.29 456.93 3.50 5959687.26 599547.61 MWD 1900.00 48.69 62.80 1734.10 1651.60 329.84 473.51 3.50 5959696.03 599564.07 MWD 1925.00 49.56 62.96 1750.46 1667.96 338.46 490.33 3.50 5959704.87 599580.78 MWD 1950.00 50.43 63.13 1766.53 1684.03 347.14 507.40 3.50 5959713.77 599597.73 MWD . . BP BP Planning Report Company: BPAmøco Dåte: 8/2512004.. . .... .TiJDe: 15:41:31 fllge; ·4 Field: Prudhoe B~y Co--,ordÙlate(NE).Referenc:e: W~II:.·~lanZ~210;Tr1JeN()"1'I Site: PB Z Pad Vertieal(I.'VD) Relerenc:",: 54+28J) 82.!) Well: Plan Z-210 Section (VS) Relerenu: Well (O(OON;().OO~;'1'O:~IØ) WeDpatb: PlanZ-210 PB1 Survey CaJc:ullltionMetb~: Minimum Curvature»"; Oracle Survey MD Ine:! Azim TVD SYt TVD NIS EIW ft deg deg ft ft ft ft 1975.00 51.29 63.28 1782.31 1699.81 355.88 524.71 3.50 5959722.74 599614.92 MWD 1975.31 51.30 63.29 1782.50 1700.00 355.99 524.92 3.50 5959722.85 599615.14 SV5 2000.00 52.16 63.44 1797.79 1715.29 364.68 542.25 3.50 5959731.77 599632.35 MWD 2025.00 53.03 63.59 1812.98 1730.48 373.54 560.03 3.50 5959740.86 599650.00 MWD 2050.00 53.89 63.74 1827.86 1745.36 382.45 578.03 3.50 5959750.00 599667.88 MWD 2075.00 54.76 63.88 1842.44 1759.94 391.41 596.25 3.50 5959759.21 599685.98 MWD 2096.32 55.50 64.00 1854.63 1772.13 399.10 611.96 3.50 5959767.10 599701.59 End Dir : 2096 2100.00 55.50 64.00 1856.72 1774.22 400.43 614.69 0.00 5959768.46 599704.30 MWD 2125.00 55.50 64.00 1870.88 1788.38 409.46 633.21 0.00 5959777.74 599722.70 MWD 2150.00 55.50 64.00 1885.04 1802.54 418.49 651.73 0.00 5959787.01 599741.09 MWD 2175.00 55.50 64.00 1899.20 1816.70 427.52 670.24 0.00 5959796.29 599759.49 MWD 2198.49 55.50 64.00 1912.50 1830.00 436.01 687.64 0.00 5959805.00 599776.77 Base Permafrost 2200.00 55.50 64.00 1913.36 1830.86 436.56 688.76 0.00 5959805.56 599777.88 MWD 2216.14 55.50 64.00 1922.50 1840.00 442.39 700.72 0.00 5959811.55 599789.76 SV4 2225.00 55.50 64.00 1927.52 1845.02 445.59 707.28 0.00 5959814.83 599796.28 MWD 2250.00 55.50 64.00 1941.68 1859.18 454.62 725.80 0.00 5959824.11 599814.68 MWD 2275.00 55.50 64.00 1955.84 1873.34 463.65 744.32 0.00 5959833.38 599833.07 MWD 2282.35 55.50 64.00 1960.00 1877.50 466.31 749.76 0.00 5959836.11 599838.48 Start Dir 4/100 2300.00 55.42 64.85 1970.01 1887.51 472.58 762.87 4.00 5959842.56 599851.51 MWD 2325.00 55.32 66.06 1984.21 1901.71 481.13 781.59 4.00 5959851.35 599870.10 MWD 2330.77 55.30 66.34 1987.50 1905.00 483.04 785.93 4.00 5959853.32 599874.42 Fault #1 2350.00 55.23 67.27 1998.45 1915.95 489.27 800.45 4.00 5959859.73 599888.86 MWD 2375.00 55.16 68.49 2012.72 1930.22 496.99 819.47 4.00 5959867.71 599907.77 MWD 2400.00 55.09 69.70 2027.02 1944.52 504.31 838.63 4.00 5959875.28 599926.83 MWD 2425.00 55.04 70.92 2041.33 1958.83 511.22 857.93 4.00 5959882.44 599946.04 MWD 2450.00 55.00 72.14 2055.67 1973.17 517.71 877.36 4.00 5959889.18 599965.38 MWD 2475.00 54.98 73.36 2070.01 1987.51 523.78 896.91 4.00 5959895.51 599984.85 MWD 2500.00 54.96 74.58 2084.36 2001.86 529.43 916.59 4.00 5959901.42 600004.44 MWD 2525.00 54.96 75.80 2098.71 2016.21 534.66 936.37 4.00 5959906.91 600024.16 MWD 2550.00 54.97 77.03 2113.07 2030.57 539.47 956.27 4.00 5959911.98 600043.99 MWD 2575.00 54.99 78.25 2127.41 2044.91 543.85 976.27 4.00 5959916.63 600063.93 MWD 2600.00 55.02 79.47 2141.75 2059.25 547.81 996.36 4.00 5959920.85 600083.96 MWD 2625.00 55.07 80.69 2156.07 2073.57 551.34 1016.54 4.00 5959924.65 600104.10 MWD 2636.23 55.09 81.23 2162.50 2080.00 552.79 1025.63 4.00 5959926.21 600113.17 SV3 2650.00 55.13 81.90 2170.38 2087.88 554.44 1036.81 4.00 5959928.02 600124.32 MWD 2675.00 55.20 83.12 2184.66 2102.16 557.12 1057.16 4.00 5959930.96 600144.62 MWD 2700.00 55.28 84.33 2198.91 2116.41 559.36 1077.57 4.00 5959933.47 600165.01 MWD 2725.00 55.37 85.54 2213.14 2130.64 561.18 1098.05 4.00 5959935.56 600185.46 MWD 2738.75 55.43 86.21 2220.95 2138.45 561.99 1109.34 4.00 5959936.52 600196.74 End Dir : 2738 2750.00 55.43 86.21 2227.33 2144.83 562.61 1118.58 0.00 5959937.26 600205.97 MWD 2775.00 55.43 86.21 2241.51 2159.01 563.97 1139.12 0.00 5959938.89 600226.49 MWD 2800.00 55.43 86.21 2255.70 2173.20 565.33 1159.66 0.00 5959940.52 600247.01 MWD 2825.00 55.43 86.21 2269.88 2187.38 566.69 1180.21 0.00 5959942.15 600267.53 MWD 2850.00 55.43 86.21 2284.07 2201.57 568.05 1200.75 0.00 5959943.79 600288.05 MWD 2875.00 55.43 86.21 2298.25 2215.75 569.42 1221.29 0.00 5959945.42 600308.57 MWD 2900.00 55.43 86.21 2312.44 2229.94 570.78 1241.83 0.00 5959947.05 600329.08 MWD 2925.00 55.43 86.21 2326.62 2244.12 572.14 1262.37 0.00 5959948.68 600349.60 MWD 2950.00 55.43 86.21 2340.81 2258.31 573.50 1282.91 0.00 5959950.32 600370.12 MWD 2975.00 55.43 86.21 2354.99 2272.49 574.86 1303.45 0.00 5959951.95 600390.64 MWD 3000.00 55.43 86.21 2369.17 2286.67 576.23 1323.99 0.00 5959953.58 600411.16 MWD 3023.48 55.43 86.21 2382.50 2300.00 577.51 1343.29 0.00 5959955.12 600430.44 SV2 3025.00 55.43 86.21 2383.36 2300.86 577.59 1344.53 0.00 5959955.22 600431.68 MWD 3050.00 55.43 86.21 2397.54 2315.04 578.95 1365.08 0.00 5959956.85 600452.20 MWD . . BP BP Planning Report (JODìpaIlY: BP Amoco Date:> 81251200.4; . Time:1~;~l:$f.. ..\». Page: 5 Field: Prudhoe Bay Co-Q~dina~)~erere~e: Well: P'¡in Z-210';~rue~0{th Site: PBZ Pad Vertieal (TVD)Reference: 54+28.5 82.5 WeD: PlanZ-210 Section (VS)Refereøce: .. ............ Well (0.OON,o.00~,~9·~~@) WeDpath: Plan Z-21 0 PB1 Survey Calçulation \fetl)i)d: Minimum Curvature DI# Oracle Survey MD Ind Azim TVD S~TVD N/S EIW DLS MapN ~riPE ft deg deg ft ft ft ft dèg/1 ()()ft ft ... 3075.00 55.43 86.21 2411.73 2329.23 580.31 1385.62 0.00 5959958.48 600472.72 MWD 3100.00 55.43 86.21 2425.91 2343.41 581.68 1406.16 0.00 5959960.11 600493.24 MWD 3125.00 55.43 86.21 2440.10 2357.60 583.04 1426.70 0.00 5959961.75 600513.76 MWD 3150.00 55.43 86.21 2454.28 2371.78 584.40 1447.24 0.00 5959963.38 600534.28 MWD 3175.00 55.43 86.21 2468.47 2385.97 585.76 1467.78 0.00 5959965.01 600554.80 MWD 3200.00 55.43 86.21 2482.65 2400.15 587.12 1488.32 0.00 5959966.64 600575.32 MWD 3225.00 55.43 86.21 2496.84 2414.34 588.49 1508.86 0.00 5959968.28 600595.84 MWD 3250.00 55.43 86.21 2511.02 2428.52 589.85 1529.40 0.00 5959969.91 600616.36 MWD 3275.00 55.43 86.21 2525.21 2442.71 591.21 1549.95 0.00 5959971.54 600636.88 MWD 3300.00 55.43 86.21 2539.39 2456.89 592.57 1570.49 0.00 5959973.18 600657.40 MWD 3325.00 55.43 86.21 2553.58 2471.08 593.93 1591.03 0.00 5959974.81 600677.92 MWD 3350.00 55.43 86.21 2567.76 2485.26 595.30 1611.57 0.00 5959976.44 600698.44 MWD 3375.00 55.43 86.21 2581.95 2499.45 596.66 1632.11 0.00 5959978.07 600718.96 MWD 3400.00 55.43 86.21 2596.13 2513.63 598.02 1652.65 0.00 5959979.71 600739.48 MWD 3425.00 55.43 86.21 2610.32 2527.82 599.38 1673.19 0.00 5959981.34 600760.00 MWD 3450.00 55.43 86.21 2624.50 2542.00 600.75 1693.73 0.00 5959982.97 600780.52 MWD 3475.00 55.43 86.21 2638.68 2556.18 602.11 1714.28 0.00 5959984.60 600801.03 MWD 3500.00 55.43 86.21 2652.87 2570.37 603.47 1734.82 0.00 5959986.24 600821.55 MWD 3525.00 55.43 86.21 2667.05 2584.55 604.83 1755.36 0.00 5959987.87 600842.07 MWD 3550.00 55.43 86.21 2681.24 2598.74 606.19 1775.90 0.00 5959989.50 600862.59 MWD 3575.00 55.43 86.21 2695.42 2612.92 607.56 1796.44 0.00 5959991.14 600883.11 MWD 3600.00 55.43 86.21 2709.61 2627.11 608.92 1816.98 0.00 5959992.77 600903.63 MWD 3625.00 55.43 86.21 2723.79 2641.29 610.28 1837.52 0.00 5959994.40 600924.15 MWD 3640.35 55.43 86.21 2732.50 2650.00 611.12 1850.13 0.00 5959995.40 600936.75 SV1 3650.00 55.43 86.21 2737.98 2655.48 611.64 1858.06 0.00 5959996.03 600944.67 MWD 3675.00 55.43 86.21 2752.16 2669.66 613.00 1878.60 0.00 5959997.67 600965.19 MWD 3700.00 55.43 86.21 2766.35 2683.85 614.37 1899.15 0.00 5959999.30 600985.71 MWD 3725.00 55.43 86.21 2780.53 2698.03 615.73 1919.69 0.00 5960000.93 601006.23 MWD 3750.00 55.43 86.21 2794.72 2712.22 617.09 1940.23 0.00 5960002.56 601026.75 MWD 3775.00 55.43 86.21 2808.90 2726.40 618.45 1960.77 0.00 5960004.20 601047.27 MWD 3800.00 55.43 86.21 2823.09 2740.59 619.81 1981.31 0.00 5960005.83 601067.79 MWD 3816.59 55.43 86.21 2832.50 2750.00 620.72 1994.94 0.00 5960006.91 601081.41 95/8" 3825.00 55.43 86.21 2837.27 2754.77 621.18 2001.85 0.00 5960007.46 601088.31 MWD 3850.00 55.43 86.21 2851.46 2768.96 622.54 2022.39 0.00 5960009.10 601108.83 MWD 3875.00 55.43 86.21 2865.64 2783.14 623.90 2042.93 0.00 5960010.73 601129.35 MWD 3900.00 55.43 86.21 2879.82 2797.32 625.26 2063.47 0.00 5960012.36 601149.87 MWD 3925.00 55.43 86.21 2894.01 2811.51 626.63 2084.02 0.00 5960013.99 601170.39 MWD 3950.00 55.43 86.21 2908.19 2825.69 627.99 2104.56 0.00 5960015.63 601190.91 MWD 3975.00 55.43 86.21 2922.38 2839.88 629.35 2125.10 0.00 5960017.26 601211.43 MWD 4000.00 55.43 86.21 2936.56 2854.06 630.71 2145.64 0.00 5960018.89 601231.95 MWD 4025.00 55.43 86.21 2950.75 2868.25 632.07 2166.18 0.00 5960020.52 601252.47 MWD 4050.00 55.43 86.21 2964.93 2882.43 633.44 2186.72 0.00 5960022.16 601272.99 MWD 4075.00 55.43 86.21 2979.12 2896.62 634.80 2207.26 0.00 5960023.79 601293.50 MWD 4100.00 55.43 86.21 2993.30 2910.80 636.16 2227.80 0.00 5960025.42 601314.02 MWD 4125.00 55.43 86.21 3007.49 2924.99 637.52 2248.34 0.00 5960027.06 601334.54 MWD 4150.00 55.43 86.21 3021.67 2939.17 638.88 2268.89 0.00 5960028.69 601355.06 MWD 4175.00 55.43 86.21 3035.86 2953.36 640.25 2289.43 0.00 5960030.32 601375.58 MWD 4200.00 55.43 86.21 3050.04 2967.54 641.61 2309.97 0.00 5960031.95 601396.10 MWD 4225.00 55.43 86.21 3064.23 2981.73 642.97 2330.51 0.00 5960033.59 601416.62 MWD 4250.00 55.43 86.21 3078.41 2995.91 644.33 2351.05 0.00 5960035.22 601437.14 MWD 4266.02 55.43 86.21 3087.50 3005.00 645.21 2364.21 0.00 5960036.27 601450.29 UG4 4275.00 55.43 86.21 3092.60 3010.10 645.69 2371.59 0.00 5960036.85 601457.66 MWD . . BP BP Planning Report Company: BP Amoco Date: . 8/:2512004. .... ....<)Time: Field: Prudhoe Bay Co;ordinate(lllE)R~rerenee: Site: PB<Z Pad Vettl~ (TVD)R~~renee: Well: PlanZ·210 Seçtion (VS) Rer~renee: WelIpath: Plan Z-210 PB1 Survey CaleuJ4ti0u Method: Survey MD Inel Azim TVD SysTVD N/S EIW DLS Mapj!il ft deg deg ft ft ft ft (egl100ft ft 4300.00 55.43 86.21 3106.78 3024.28 647.06 2392.13 0.00 5960038.48 601478.18 MWD 4325.00 55.43 86.21 3120.96 3038.46 648.42 2412.67 0.00 5960040.12 601498.70 MWD 4345.33 55.43 86.21 3132.50 3050.00 649.53 2429.38 0.00 5960041.44 601515.39 UG4A 4350.00 55.43 86.21 3135.15 3052.65 649.78 2433.22 0.00 5960041.75 601519.22 MWD 4375.00 55.43 86.21 3149.33 3066.83 651.14 2453.76 0.00 5960043.38 601539.74 MWD 4400.00 55.43 86.21 3163.52 3081.02 652.51 2474.30 0.00 5960045.02 601560.26 MWD 4425.00 55.43 86.21 3177.70 3095.20 653.87 2494.84 0.00 5960046.65 601580.78 MWD 4450.00 55.43 86.21 3191.89 3109.39 655.23 2515.38 0.00 5960048.28 601601.30 MWD 4475.00 55.43 86.21 3206.07 3123.57 656.59 2535.92 0.00 5960049.91 601621.82 MWD 4500.00 55.43 86.21 3220.26 3137.76 657.95 2556.46 0.00 5960051.55 601642.34 MWD 4525.00 55.43 86.21 3234.44 3151.94 659.32 2577.00 0.00 5960053.18 601662.86 MWD 4550.00 55.43 86.21 3248.63 3166.13 660.68 2597.54 0.00 5960054.81 601683.38 MWD 4575.00 55.43 86.21 3262.81 3180.31 662.04 2618.09 0.00 5960056.44 601703.90 MWD 4600.00 55.43 86.21 3277.00 3194.50 663.40 2638.63 0.00 5960058.08 601724.42 MWD 4625.00 55.43 86.21 3291.18 3208.68 664.76 2659.17 0.00 5960059.71 601744.94 MWD 4650.00 55.43 86.21 3305.37 3222.87 666.13 2679.71 0.00 5960061.34 601765.45 MWD 4675.00 55.43 86.21 3319.55 3237.05 667.49 2700.25 0.00 5960062.98 601785.97 MWD 4700.00 55.43 86.21 3333.74 3251.24 668.85 2720.79 0.00 5960064.61 601806.49 MWD 4725.00 55.43 86.21 3347.92 3265.42 670.21 2741.33 0.00 5960066.24 601827.01 MWD 4750.00 55.43 86.21 3362.10 3279.60 671.58 2761.87 0.00 5960067.87 601847.53 MWD 4775.00 55.43 86.21 3376.29 3293.79 672.94 2782.41 0.00 5960069.51 601868.05 MWD 4800.00 55.43 86.21 3390.47 3307.97 674.30 2802.96 0.00 5960071.14 601888.57 MWD 4825.00 55.43 86.21 3404.66 3322.16 675.66 2823.50 0.00 5960072.77 601909.09 MWD 4850.00 55.43 86.21 3418.84 3336.34 677.02 2844.04 0.00 5960074.40 601929.61 MWD 4875.00 55.43 86.21 3433.03 3350.53 678.39 2864.58 0.00 5960076.04 601950.13 MWD 4900.00 55.43 86.21 3447.21 3364.71 679.75 2885.12 0.00 5960077.67 601970.65 MWD 4925.00 55.43 86.21 3461.40 3378.90 681.11 2905.66 0.00 5960079.30 601991.17 MWD 4935.75 55.43 86.21 3467.50 3385.00 681.70 2914.50 0.00 5960080.00 602000.00 Z-210 PB1 T1 4950.00 55.35 85.52 3475.59 3393.09 682.54 2926.19 4.00 5960081.00 602011.68 MWD 4975.00 55.23 84.31 3489.83 3407.33 684.36 2946.66 4.00 5960083.09 602032.12 MWD 5000.00 55.12 83.10 3504.10 3421.60 686.61 2967.06 4.00 5960085.61 602052.49 MWD 5025.00 55.01 81.89 3518.42 3435.92 689.29 2987.38 4.00 5960088.56 602072.77 MWD 5050.00 54.93 80.67 3532.77 3450.27 692.39 3007.61 4.00 5960091.93 602092.96 MWD 5075.00 54.85 79.45 3547.15 3464.65 695.92 3027.76 4.00 5960095.72 602113.05 MWD 5100.00 54.78 78.23 3561.56 3479.06 699.87 3047.80 4.00 5960099.94 602133.04 MWD 5125.00 54.73 77.01 3575.98 3493.48 704.25 3067.74 4.00 5960104.57 602152.92 MWD 5150.00 54.69 75.79 3590.43 3507.93 709.05 3087.58 4.00 5960109.63 602172.69 MWD 5175.00 54.66 74.56 3604.88 3522.38 714.27 3107.30 4.00 5960115.11 602192.33 MWD 5200.00 54.65 73.34 3619.35 3536.85 719.90 3126.89 4.00 5960121.01 602211.85 MWD 5225.00 54.64 72.11 3633.81 3551.31 725.96 3146.36 4.00 5960127.32 602231.24 MWD 5250.00 54.65 70.88 3648.28 3565.78 732.43 3165.70 4.00 5960134.04 602250.48 MWD 5275.00 54.67 69.66 3662.74 3580.24 739.32 3184.89 4.00 5960141.18 602269.58 MWD 5300.00 54.71 68.43 3677.19 3594.69 746.61 3203.94 4.00 5960148.73 602288.54 MWD 5325.00 54.75 67.21 3691.62 3609.12 754.32 3222.84 4.00 5960156.68 602307.33 MWD 5350.00 54.81 65.99 3706.04 3623.54 762.43 3241.59 4.00 5960165.04 602325.96 MWD 5375.00 54.88 64.77 372D.43 3637.93 770.94 3260.17 4.00 5960173.80 602344.43 MWD 5400.00 54.97 63.55 3734.80 3652.30 779.86 3278.58 4.00 5960182.95 602362.72 MWD 5425.00 55.06 62.33 3749.14 3666.64 789.18 3296.82 4.00 5960192.51 602380.84 MWD 5450.00 55.17 61.12 3763.44 3680.94 798.89 3314.88 4.00 5960202.46 602398.77 MWD 5475.00 55.29 59.91 3777 .69 3695.19 809.00 3332.76 4.00 5960212.80 602416.50 MWD 5500.00 55.42 58.71 3791.91 3709.41 819.49 3350.44 4.00 5960223.53 602434.05 MWD 5509.87 55.47 58.23 3797.50 3715.00 823.74 3357.37 4.00 5960227.87 602440.92 End Dir : 5509 5525.00 55.47 58.23 3806.08 3723.58 830.31 3367.97 0.00 5960234.57 602451.43 MWD . . BP BP Planning Report Company: BP Amoco Date: 812512()()4 ....Timll;i15:41:~1..ii.? (ii. Pågll: 1 Fillld: Prudh~ Bay cø-ordinate(Nl:)RllfllrmCII;yiell: PlanZ"41~fT~iW~rth Sitll: PB Z Pad Vllrtical (TVI)RefllrllnCII;54+28.5 82.5 wen; Plan Z-210 SlIclion (VslReferencII; ....... Well (0.oo\J,9.~i7Q.·~i) WIIUpath: Plan Z-210 PB1 Surny Calcllladon~~h04; MinimumCutVature 00; 0råcIe Survey MD loci Azim TVD Sys TVD E/W ft deg deg ft ft ft 5550.00 55.47 58.23 3820.25 3737.75 841.15 3385.48 0.00 5960245.64 602468.80 MWD 5575.00 55.47 58.23 3834.42 3751.92 851.99 3402.99 0.00 5960256.71 602486.16 MWD 5600.00 55.47 58.23 3848.59 3766.09 862.84 3420.50 0.00 5960267.79 602503.53 MWD 5625.00 55.47 58.23 3862.76 3780.26 873.68 3438.02 0.00 5960278.86 602520.89 MWD 5650.00 55.47 58.23 3876.93 3794.43 884.52 3455.53 0.00 5960289.93 602538.26 MWD 5675.00 55.47 58.23 3891.10 3808.60 895.37 3473.04 0.00 5960301.00 602555.62 MWD 5700.00 55.47 58.23 3905.27 3822.77 906.21 3490.55 0.00 5960312.07 602572.99 MWD 5725.00 55.47 58.23 3919.44 3836.94 917.05 3508.06 0.00 5960323.15 602590.35 MWD 5750.00 55.47 58.23 3933.61 3851.11 927.89 3525.57 0.00 5960334.22 602607.72 MWD 5775.00 55.47 58.23 3947.78 3865.28 938.74 3543.08 0.00 5960345.29 602625.08 MWD 5800.00 55.47 58.23 3961.95 3879.45 949.58 3560.59 0.00 5960356.36 602642.45 MWD 5825.00 55.47 58.23 3976.12 3893.62 960.42 3578.11 0.00 5960367.43 602659.81 MWD 5850.00 55.47 58.23 3990.29 3907.79 971.27 3595.62 0.00 5960378.51 602677.18 MWD 5862.72 55.47 58.23 3997.50 3915.00 976.78 3604.53 0.00 5960384.14 602686.01 UG1 5875.00 55.47 58.23 4004.46 3921.96 982.11 3613.13 0.00 5960389.58 602694.54 MWD 5900.00 55.47 58.23 4018.63 3936.13 992.95 3630.64 0.00 5960400.65 602711.91 MWD 5925.00 55.47 58.23 4032.80 3950.30 1003.80 3648.15 0.00 5960411.72 602729.27 MWD 5950.00 55.47 58.23 4046.97 3964.47 1014.64 3665.66 0.00 5960422.79 602746.64 MWD 5975.00 55.47 58.23 4061.14 3978.64 1025.48 3683.17 0.00 5960433.86 602764.00 MWD 6000.00 55.47 58.23 4075.31 3992.81 1036.32 3700.68 0.00 5960444.94 602781.37 MWD 6025.00 55.47 58.23 4089.48 4006.98 1047.17 3718.20 0.00 5960456.01 602798.73 MWD 6050.00 55.47 58.23 4103.65 4021.15 1058.01 3735.71 0.00 5960467.08 602816.10 MWD 6075.00 55.47 58.23 4117.82 4035.32 1068.85 3753.22 0.00 5960478.15 602833.47 MWD 6100.00 55.47 58.23 4131.99 4049.49 1079.70 3770.73 0.00 5960489.22 602850.83 MWD 6125.00 55.47 58.23 4146.16 4063.66 1090.54 3788.24 0.00 5960500.30 602868.20 MWD 6150.00 55.47 58.23 4160.33 4077.83 1101.38 3805.75 0.00 5960511.37 602885.56 MWD 6175.00 55.47 58.23 4174.50 4092.00 1112.22 3823.26 0.00 5960522.44 602902.93 MWD 6200.00 55.47 58.23 4188.67 4106.17 1123.07 3840.77 0.00 5960533.51 602920.29 MWD 6225.00 55.47 58.23 4202.84 4120.34 1133.91 3858.29 0.00 5960544.58 602937.66 MWD 6250.00 55.47 58.23 4217.01 4134.51 1144.75 3875.80 0.00 5960555.66 602955.02 MWD 6275.00 55.47 58.23 4231.18 4148.68 1155.60 3893.31 0.00 5960566.73 602972.39 MWD 6300.00 55.47 58.23 4245.35 4162.85 1166.44 3910.82 0.00 5960577.80 602989.75 MWD 6325.00 55.47 58.23 4259.52 4177.02 1177.28 3928.33 0.00 5960588.87 603007.12 MWD 6350.00 55.47 58.23 4273.69 4191.19 1188.13 3945.84 0.00 5960599.94 603024.48 MWD 6374.37 55.47 58.23 4287.50 4205.00 1198.70 3962.91 0.00 5960610.74 603041 .41 Ma 6375.00 55.47 58.23 4287.86 4205.36 1198.97 3963.35 0.00 5960611.02 603041.85 MWD 6400.00 55.47 58.23 4302.03 4219.53 1209.81 3980.86 0.00 5960622.09 603059.21 MWD 6425.00 55.47 58.23 4316.20 4233.70 1220.65 3998.38 0.00 5960633.16 603076.58 MWD 6450.00 55.47 58.23 4330.37 4247.87 1231.50 4015.89 0.00 5960644.23 603093.94 MWD 6475.00 55.47 58.23 4344.54 4262.04 1242.34 4033.40 0.00 5960655.30 603111.31 MWD 6480.23 55.47 58.23 4347.50 4265.00 1244.61 4037.06 0.00 5960657.62 603114.94 Mb1 6500.00 55.47 58.23 4358.71 4276.21 1253.18 4050.91 0.00 5960666.38 603128.67 MWD 6525.00 55.47 58.23 4372.88 4290.38 1264.03 4068.42 0.00 5960677.45 603146.04 MWD 6550.00 55.47 58.23 4387.05 4304.55 1274.87 4085.93 0.00 5960688.52 603163.40 MWD 6568.44 55.47 58.23 4397.50 4315.00 1282.87 4098.85 0.00 5960696.69 603176.22 Mb2 6575.00 55.47 58.23 4401.22 4318.72 1285.71 4103.44 0.00 5960699.59 603180.77 MWD 6600.00 55.47 58.23 4415.39 4332.89 1296.56 4120.96 0.00 5960710.66 603198.14 MWD 6625.00 55.47 58.23 4429.56 4347.06 1307.40 4138.47 0.00 5960721.74 603215.50 MWD 6650.00 55.47 58.23 4443.73 4361.23 1318.24 4155.98 0.00 5960732.81 603232.87 MWD 6675.00 55.47 58.23 4457.90 4375.40 1329.08 4173.49 0.00 5960743.88 603250.23 MWD 6691.95 55.47 58.23 4467.50 4385.00 1336.43 4185.36 0.00 5960751.38 603262.00 Me 6700.00 55.47 58.23 4472.07 4389.57 1339.93 4191.00 0.00 5960754.95 603267.60 MWD . . BP BP Planning Report Company: 6P Amoco Date: 8/2512004 . Time: 15:41:31... . ..... ........ge: 8 Field: Prudhoe Bay Co-ordinate(NE) Rererenc~: Well? Plegz.,.2tQ;Tru& NOI"tt) Site: P6 Z Pad Vertical (TVD) Rer~rence: 54+28.58.2.5 WeD: Plan Z-210 Section Q'S)l~dere~:. / W&II (0.OQ~!0.qQE;!7Q.88N:j) WeDpath: Plan Z-210 PB1 SurveyCalcu..tion.M~hod: Minimum Curvature Dh: Ol'ac:!~ Survey MD IlIcl Azim TV» Sy. TVO. N/S EIW DLS MapN ·M~pF: ft deg deg ft ft ft ft degl100ft ft .ft .. 6725.00 55.47 58.23 4486.23 4403.73 1350.77 4208.51 0.00 5960766.02 603284.96 MWD 6750.00 55.47 58.23 4500.40 4417.90 1361.61 4226.02 0.00 5960777.10 603302.33 MWD 6775.00 55.47 58.23 4514.57 4432.07 1372.46 4243.53 0.00 5960788.17 603319.69 MWD 6800.00 55.47 58.23 4528.74 4446.24 1383.30 4261.05 0.00 5960799.24 603337.06 MWD 6806.63 55.47 58.23 4532.50 4450.00 1386.17 4265.69 0.00 5960802.17 603341.66 Na 6825.00 55.47 58.23 4542.91 4460.41 1394.14 4278.56 0.00 5960810.31 603354.42 MWD 6850.00 55.47 58.23 4557.08 4474.58 1404.98 4296.07 0.00 5960821.38 603371.79 MWD 6850.73 55.47 58.23 4557.50 4475.00 1405.30 4296.58 0.00 5960821.71 603372.30 Nb 6875.00 55.47 58.23 4571.25 4488.75 1415.83 4313.58 0.00 5960832.46 603389.15 MWD 6900.00 55.47 58.23 4585.42 4502.92 1426.67 4331.09 0.00 5960843.53 603406.52 MWD 6921.31 55.47 58.23 4597.50 4515.00 1435.91 4346.01 0.00 5960852.96 603421.32 Nc 6925.00 55.47 58.23 4599.59 4517.09 1437.51 4348.60 0.00 5960854.60 603423.88 MWD 6950.00 55.47 58.23 4613.76 4531.26 1448.36 4366.11 0.00 5960865.67 603441.25 MWD 6975.00 55.47 58.23 4627.93 4545.43 1459.20 4383.62 0.00 5960876.74 603458.61 MWD 7000.00 55.47 58.23 4642.10 4559.60 1470.04 4401.14 0.00 5960887.82 603475.98 MWD 7025.00 55.47 58.23 4656.27 4573.77 1480.89 4418.65 0.00 5960898.89 603493.34 MWD 7050.00 55.47 58.23 4670.44 4587.94 1491.73 4436.16 0.00 5960909.96 603510.71 MWD 7075.00 55.47 58.23 4684.61 4602.11 1502.57 4453.67 0.00 5960921.03 603528.07 MWD 7100.00 55.47 58.23 4698.78 4616.28 1513.41 4471.18 0.00 5960932.10 603545.44 MWD 7106.56 55.47 58.23 4702.50 4620.00 1516.26 4475.77 0.00 5960935.01 603549.99 Z-210 PB1 T2 7125.00 55.35 59.12 4712.97 4630.47 1524.15 4488.74 4.00 5960943.07 603562.86 MWD 7150.00 55.19 60.32 4727.21 4644.71 1534.51 4506.49 4.00 5960953.66 603580.46 MWD 7175.00 55.05 61.53 4741.51 4659.01 1544.48 4524.41 4.00 5960963.86 603598.25 MWD 7200.00 54.91 62.74 4755.86 4673.36 1554.05 4542.51 4.00 5960973.67 603616.22 MWD 7211.55 54.86 63.30 4762.50 4680.00 1558.34 4550.93 4.00 5960978.07 603624.58 OBa 7225.00 54.79 63.95 4770.25 4687.75 1563.22 4560.78 4.00 5960983.08 603634.36 MWD 7250.00 54.68 65.17 4784.68 4702.18 1571.99 4579.21 4.00 5960992.09 603652.68 MWD 7263.52 54.63 65.83 4792.50 4710.00 1576.56 4589.24 4.00 5960996.80 603662.65 OBb 7275.00 54.59 66.39 4799.15 4716.65 1580.35 4597.80 4.00 5961000.70 603671.16 MWD 7300.00 54.50 67.61 4813.65 4731.15 1588.31 4616.55 4.00 5961008.90 603689.79 MWD 7325.00 54.43 68.84 4828.18 4745.68 1595.86 4635.44 4.00 5961016.70 603708.58 MWD 7341.01 54.39 69.62 4837.50 4755.00 1600.48 4647.61 4.00 5961021.48 603720.69 OBc 7341.27 54.39 69.64 4837.65 4755.15 1600.55 4647.81 4.00 5961021.55 603720.89 End Dir : 7:A1 7350.00 54.39 69.64 4842.73 4760.23 1603.02 4654.46 0.00 5961024.11 603727.51 MWD 7375.00 54.39 69.64 4857.29 4774.79 1610.09 4673.52 0.00 5961031.43 603746.47 MWD 7400.00 54.39 69.64 4871.85 4789.35 1617.17 4692.57 0.00 5961038.75 603765.42 MWD 7425.00 54.39 69.64 4886.40 4803.90 1624.24 4711.63 0.00 5961046.08 603784.38 MWD 7444.06 54.39 69.64 4897.50 4815.00 1629.63 4726.15 0.00 5961051.66 603798.84 OBd 7450.00 54.39 69.64 4900.96 4818.46 1631.31 4730.68 0.00 5961053.40 603803.34 MWD 7475.00 54.39 69.64 4915.52 4833.02 1638.38 4749.74 0.00 5961060.72 603822.30 MWD 7500.00 54.39 69.64 4930.07 4847.57 1645.46 4768.79 0.00 5961068.05 603841.26 MWD 7525.00 54.39 69.64 4944.63 4862.13 1652.53 4787.85 0.00 5961075.37 603860.22 MWD 7550.00 54.39 69.64 4959.18 4876.68 1659.60 4806.90 0.00 5961082.69 603879.17 MWD 7555.69 54.39 69.64 4962.50 4880.00 1661.22 4811.24 0.00 5961084.36 603883.49 OBe 7575.00 54.39 69.64 4973.74 4891.24 1666.68 4825.96 0.00 5961090.02 603898.13 MWD 7600.00 54.39 69.64 4988.30 4905.80 1673.75 4845.01 0.00 5961097.34 603917.09 MWD 7615.81 54.39 69.64 4997.50 4915.00 1678.22 4857.06 0.00 5961101.97 603929.08 OBf 7625.00 54.39 69.64 5002.85 4920.35 1680.82 4864.07 0.00 5961104.66 603936.05 MWD 7650.00 54.39 69.64 5017.41 4934.91 1687.90 4883.12 0.00 5961111.99 603955.01 MWD 7675.00 54.39 69.64 5031.97 4949.47 1694.97 4902.17 0.00 5961119.31 603973.96 MWD 7700.00 54.39 69.64 5046.52 4964.02 1702.04 4921.23 0.00 5961126.63 603992.92 MWD 7701.68 54.39 69.64 5047.50 4965.00 1702.52 4922.51 0.00 5961127.12 603994.19 OBCBase 7725.00 54.39 69.64 5061.08 4978.58 1709.12 4940.28 0.00 5961133.95 604011.88 MWD . . BP BP Planning Report Company: BP A/TIC>CO Batte: 8I2~120Q4 . Time: 15:41:31 ..<~e: " Field: PrudboeBay Co-ordinate(NE) Referenœ: Well: Plan. Z.210,'True NQt1h Site: PB Z Pad Vertiçal (TVD).lùferênœ: 54+28.582.5 WeU: PlanZ-210 Sêçtlon (VS) Reference: Well (O.OON.0.OO§,70.~) WeDpath: PlanZ·210 PB1 SurVey CalcnlatlOn Meth~: Minimum Curvature Db: Oracle Survey MD Ind Azim TV» SysTV» N/S EI\V DLS MapN . MriPE ft deg deg ft ft ft ft deg/100ft ft ... 7750.00 54.39 69.64 5075.64 4993.14 1716.19 4959.34 0.00 5961141.28 604030.84 MWD 7775.00 54.39 69.64 5090.19 5007.69 1723.26 4978.39 0.00 5961148.60 604049.80 MWD 7800.00 54.39 69.64 5104.75 5022.25 1730.33 4997.45 0.00 5961155.92 604068.75 MWD 7825.00 54.39 69.64 5119.30 5036.80 1737.41 5016.50 0.00 5961163.25 604087.71 MWD 7850.00 54.39 69.64 5133.86 5051.36 1744.48 5035.56 0.00 5961170.57 604106.67 MWD 7875.00 54.39 69.64 5148.42 5065.92 1751.55 5054.61 0.00 5961177.89 604125.63 MWD 7900.00 54.39 69.64 5162.97 5080.47 1758.63 5073.67 0.00 5961185.22 604144.59 MWD 7916.36 54.39 69.64 5172.50 5090.00 1763.26 5086.14 0.00 5961190.01 604156.99 Z-210 PB1 T3 REF.ERENCE fNFORMA nON SURVEY PROGRAM P!.an: l~2¡O wp07 (pJan Z~2IO¡P¡an Z.2Jü) BP }\mœo DepiliFm J::kpth To Tool Cre13ted By: Trey Jakabo¡¡ky Date: 8/25;2004 3957.ÜÚ 6947.80 Planued:Z.2IOwp(!7 \/12 MWD Checked' Date: E~1? ISeWSA ".w ~--- - Reviewed: Date ___ ,w"'''g "=,,~ ¡¡'i,;¡"B:..,¡ CASING DETAILS -Ef·\I,' Northing F..asting læ!,_ Loog:!lude 51", No. TVD MD Size P1anZ-2iÜ 2159.61 ·2HH.!! 59593('{¡.OO 59909S,ÜÜ 7{j"¡T54287N !49"! !'50H46W ¡ TARGET DETAILS 2 Name TVD +Nf-S +Ef·W Northing Easting Shape ~:~:g1'~uit 1 5959512.01 ~~~~o~ 100) 250v ljs" I i ,i.i IJ liT Z-2IOA 1'2 5959458.01 · ~ I i r i T i 3~ 1/ SECTION DETAILS ~ 'S þ' ¡ BTd }¡, See MD Ine Azi TVD +Nf-S +E/~W DLeg TFace VSee Target " , K, f' I I m¿i m ~. ~ ~ 19 I8 I 2 I~I 3 m~~ ¡ m t ~ ó ~ 300v i ~ ~~i I 4 Z-2!OA TI 5 : ??~ 1 ó !7. 1 r~¡4. 'A', ~K 6 69471 4 4 Z-210A 1"2 . " f. '" i ¡ '," ......... . i . ., 'T , . ..,. .i .. , ....... IT ,.... ....,......, . +, , · i ....i.. ...... , .... JG3 "- '~" , ,. .... . ' , ' :i , , , . · · 350v T . · ......... : .....,.., ,... ....... .... : " 'þ, ' , .... i + ·t ¡ I i , i . · · T i : ......... ....,... " .·..i·.·. J i , . ;¡;¡ ... " i ,i ,.... i· ' . i 'i 0 ....... i i······ i + i iT' 0 :!1 i¡ " · i · , ~ I I ~. · i" H , ç:, . ..,.... . . . + ¡. . ...... + .. · ,.... ~ ~wv i i , , . E i .¡ " ,. I >- · .... , " , ;: T '" i . . ..... 1'.. ..... .......... : : ' , f i . :Zi2t i , -,7f'" . ¡ " 450 ¿ i ¡ ¡ ....... ¡ 7 i 08 ;7 500 .~ ,,^ 1500 2000 2500 3000 3;'00 4000 4500 5000 5500 Vertical Section at 89.35° [500ft/in] SURVEY PROGRAM Plan: Z~21O wp07 (P!an Z·2JO/Plan Z-21O) BPArnQOO ,'rue'~w Depth Fro Deptl¡ To SurveyiPhIn 7=1 Created By: Troy Jakahosky Date: 8/25f2004 .54+28.582.50 3957.00 (Ø47.80 MWD . SloI- (O,ooN,O.ooE¡ P1annoo:Z.2iû\VþÚ7V12 Che-<:ked; Date: ~:;;': ~= ISCWSA . 54+28" 8250 \\-'ELL DETAILS '"01,,_ "'"" kÐ'~W Nartùing Eamng Lalimde SECTION DETAILS rim l-2IO 2159.61 ·21'1.11 59593&"00 '_S.OO 70017"542'7N 140'1I"O.946W NiA TARGET DETAILS See MD Ine Azi TVD +NI-S +EI·W DLeg TFace VSec Target ¡::~~:~ ~i:1~ ¡~:i¡ ~~ /, 6: ~ IS~: :¡ Name TVD +NI·S +E!-W Northing Easting Shape I 2 ~¡ I( Z-2lO I 599420.00 ~'?¡YJ!"?~ 3 ¿:~~:¿ 1L~ n~:~~ ¡~ ~. Ó ¡2~ ::¡: Z-2IOAT! <0,0,'1' (II 6028lO.00 lOO) 4 í, iJ Z-2IOA T! ~o¡y!,o~~ , 5 ~::¡U iiil : :~:g~ ~?~: Ó I7~:: ::~: 2 6 Z-2 HJA T2 Z--21OA T2 45.22 <o<o,,<~ f\¡ 200) CASING DETAILS FORMATION TOP DETAILS No. TVD MD Name Size TVDPath MDPath Formation 1 2 1 1 ~1A 2 3 4 ~i 1\ ,~'t~ ii 4 5 ~1 6 p'" .,~U 7 S i "'j'\, þ+~ þ+t 5( : 9 4 : i , i 10 4 11 4 120 i ! ,,+ +" 12 4 '"', 13 4 ~ '"'. 14 +'r" 2+/ 15 ~ 16 ~/ '\, 17 ~ IS I 41 19 o .Î:"'Base '\., 1 Ii E i¡j '\' I I i ..¡L. . , 'Ii r ..". 800 i ' ii · . , · L+ . '2 \ II , i\ , ,. , . :â , \ , i . , '" i :i IJllIOO , .. i·· . ,. 'I : ' , , +' , ""i ' j .'. i f , i ' ' 1'510 ,I , "i' .. ~ 40 .1·,' · 15' g i +. ...,. . . 00 -;+ ¡ ... II , ¡ I i I'"~ + , ) , ~ " v j : ·4 . I600 2000 2' IO 2800 3200 3600 4000 4400 4S00 5200 West(-)lEast(+) ¡4ooftlin . . BP BP Planning Report Company: Field: Site: Well: Wellpath: BP Amoco Prudl10e Bay PB Z Pad Plan Z-21 0 Plan Z-2tO Date: 8/2512004 Time: 16:12:53 Page: 1 ~~~~iD=~~:=~: ~~:'~~2:;10, True North Section (VS) Reference: Well (0.00N,O.OOE,89.35Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Plan: Z-210 wp07 Date Composed: Version: Tied-to: 6/16/2004 12 From: Definitive Path Principal: Yes Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: PB Z Pad TR-11-12 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Levet: 0.00 ft 5957230.17 ft 601304.82 ft Latitude: 70 17 Longitude: 149 10 North Reference: Grid Convergence: 33.051 N 47.365 W True 0.77 deg Well: Plan Z-210 Slot Name: Well Position: +N/-S 2159.61 ft Northing: 5959360.00 ft Latitude: 70 17 54.287 N +E/-W-2181.11 ft Easting : 599095.00 ft Longitude: 149 11 50.946 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Höle Size ft ft in in 3816.59 2832.50 9.625 12.250 9 5/8" 6947.00 5115.78 7.000 8.750 7" Formations MD TVD Formations Uthology ft ft 4228.19 3082.50 UG4 0.00 0.00 4301.97 3132.50 UG4A 0.00 0.00 4748.41 3452.50 UG3 0.00 0.00 5436.61 3952.50 UG1 0.00 0.00 5794.48 4212.50 Ma 0.00 0.00 5870.18 4267.50 Mb1 0.00 0.00 5945.89 4322.50 Mb2 0.00 0.00 6035.35 4387.50 Me 0.00 0.00 6124.82 4452.50 Na 0.00 0.00 6159.23 4477.50 Nb 0.00 0.00 6221.17 4522.50 Nc 0.00 0.00 6365.69 4627.50 OA 0.00 0.00 6446.20 4687.50 OBa 0.00 0.00 6485.04 4717.50 OBb 0.00 0.00 6541.80 4762.50 OBc 0.00 0.00 6615.03 4822.50 OBd 0.00 0.00 6691.69 4887.50 OBe 0.00 0.00 6731.99 4922.50 OBf 0.00 0.00 6782.91 4967.50 OBCBase 0.00 0.00 Targets <--Latitude ---> Name Description TVD +EI·W MiD Dip. DIr. ft ft Z-210 Fault 1 1932.50 2655.72 360.08 5962020.00 599420.00 70 18 20.406 N 149 11 40.446 W -Polygon 1 1932.50 2655.72 360.08 5962020.00 599420.00 70 18 20.406 N 149 11 40.446 W -Polygon 2 1932.50 1204.33 445.95 5960570.00 599525.00 70 18 6.132 N 149 1137.944W -Polygon 3 1932.50 489.52 801.59 5959860.00 599890.00 70 17 59.101 N 149 11 27.578 W -Polygon 4 1932.50 -952.38 2442.87 5958440.00 601550.00 70 17 44.917 N 149 10 39.744 W -Polygon 5 1932.50 489.52 801.59 5959860.00 599890.00 70 17 59.101 N 149 11 27.578 W -Polygon 6 1932.50 1204.33 445.95 5960570.00 599525.00 70 18 6.132 N 149 1137.944W Company: Field: Site: Well: Wellpath: Targets . . BP BP Planning Report BPAmoco Prudhoe Bay PB Z Pad Plan Z-210 Plan Z-210 Description Dip. Dir. Map +N/-S +EI-W Nortbing ft ft ft 4627.50 163.01 3717.80 5959572.01 602810.00 70 17 55.881 N 149 10 2.567 W 4682.50 1980.59 2636.57 5961375.00 601705.00 70 18 13.762 N 149 10 34.068 W 4682.50 1980.59 2636.57 5961375.00 601705.00 70 18 13.762 N 149 10 34.068 W 4682.50 992.93 3583.72 5960400.00 602665.00 70 18 4.044 N 149 10 6.464 W 4682.50 427.12 4016.33 5959840.00 603105.00 70 17 58.477 N 149 9 53.861 W 4682.50 189.40 4978.37 5959615.00 604070.00 70 17 56.134 N 149 9 25.820 W 4682.50 425.68 6021.67 5959865.00 605110.00 70 17 58.450 N 149 8 55.400 W 4682.50 189.40 4978.37 5959615.00 604070.00 70 17 56.134 N 149 9 25.820 W 4682.50 427.12 4016.33 5959840.00 603105.00 70 17 58.477 N 149 9 53.861 W 4682.50 992.93 3583.72 5960400.00 602665.00 70 18 4.044 N 149 10 6.464 W 4682.50 146.04 3764.20 5959555.64 602856.62 70 17 55.714 N 149 10 1.215 W 5116.50 45.22 4004.30 5959458.01 603098.00 70 17 54.721 N 149 9 54.217 W Z-210A T1 -Circle (Radius: 100) -Plan hit target Z-210 Fault 2 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 -Polygon 7 -Polygon 8 -Plan out by 2153.40 at Z-210A T2 -Circle (Radius: 200) -Plan hit target ptan Section Information 3957.00 4057.00 4533.48 6365.69 6828.61 6947.80 Survey MD ft 3816.59 3957.00 3975.00 4000.00 4025.00 4050.00 4057.00 4075.00 4100.00 4125.00 4150.00 4175.00 4200.00 4225.00 4228.19 4250.00 4275.00 4300.00 4301.97 4325.00 4350.00 4375.00 4400.00 4425.00 4450.00 Incl Azim TVD +N/-S +EI-W DLSØnlld 'furn TFQ deg d!ilg ft ft ft deg/10ot! degl100ft deg/10Qft' ..~ 55.43 86.21 2912.17 628.37 2110.31 0.00 0.00 0.00 0.00 51.43 86.21 2971.73 633.68 2190.43 4.00 -4.00 0.00 180.00 43.40 109.83 3296.35 590.07 2533.46 4.00 -1.68 4.96 122.52 43.40 109.83 4627.50 163.01 3717.80 0.00 0.00 0.00 0.00 25.11 115.05 5008.57 66.63 3958.48 4.00 -3.95 1.13 173.01 25.11 115.05 5116.50 45.22 4004.30 0.00 0.00 0.00 0.00 Target Z-210A T1 Z-210A T2 Incl Aziln TVD d!ilg deg ft ft 55.43 86.21 2832.50 2750.00 620.72 1994.94 0.00 5960006.91 601081.41 9 5/8" 55.43 86.21 2912.17 2829.67 628.37 2110.31 0.00 5960016.08 601196.65 Start Dir 4/100 54.71 86.21 2922.47 2839.97 629.35 2125.03 4.00 5960017.25 601211.36 MWD 53.71 86.21 2937.09 2854.59 630.69 2145.27 4.00 5960018.86 601231.58 MWD 52.71 86.21 2952.06 2869.56 632.01 2165.25 4.00 5960020.45 601251.53 MWD 51.71 86.21 2967.38 2884.88 633.32 2184.96 4.00 5960022.02 601271.22 MWD 51.43 86.21 2971.73 2889.23 633.68 2190.43 4.00 5960022.45 601276.69 MWD 51.05 86.99 2983.00 2900.50 634.52 2204.44 4.00 5960023.47 601290.69 MWD 50.52 88.09 2998.81 2916.31 635.35 2223.79 4.00 5960024.56 601310.02 MWD 50.01 89.20 3014.79 2932.29 635.80 2243.01 4.00 5960025.27 601329.23 MWD 49.50 90.33 3030.94 2948.44 635.88 2262.09 4.00 5960025.60 601348.31 MWD 49.01 91.48 3047.26 2964.76 635.58 2281.03 4.00 5960025.55 601367.25 MWD 48.53 92.65 3063.73 2981.23 634.91 2299.82 4.00 5960025.12 601386.04 MWD 48.06 93.83 3080.37 2997.87 633.86 2318.45 4.00 5960024.31 601404.69 MWD 48.00 93.98 3082.50 3000.00 633.69 2320.82 4.00 5960024.18 601407.06 UG4 47.60 95.03 3097.15 3014.65 632.43 2336.93 4.00 5960023.13 601423.18 MWD 47.16 96.25 3114.08 3031.58 630.62 2355.23 4.00 5960021.56 601441.51 MWD 46.73 97.48 3131.15 3048.65 628.44 2373.37 4.00 5960019.62 601459.67 MWD 46.69 97.58 3132.50 3050.00 628.25 2374.79 4.00 5960019.45 601461.09 UG4A 46.31 98.73 3148.35 3065.85 625.88 2391.33 4.00 5960017.30 601477.66 MWD 45.91 100.00 3165.68 3083.18 622.95 2409.10 4.00 5960014.60 601495.47 MWD 45.52 101.29 3183.14 3100.64 619.64 2426.69 4.00 5960011.53 601513.09 MWD 45.14 102.59 3200.72 3118.22 615.96 2444.08 4.00 5960008.08 601530.53 MWD 44.78 103.91 3218.41 3135.91 611.91 2461.28 4.00 5960004.26 601547.78 MWD 44.44 105.25 3236.20 3153.70 607.49 2478.27 4.00 5960000.06 601564.82 MWD " ~ . . BP BP Planning Report Cømpany: BP Amoco Date: 8/25/2004. ..J Time: t~;1~;53J/·J ·i.Jrd..~ltge: 3 Field: Prudhoe Bay c_rdinate(NE).Refe¡enee: Well:....Plan.z.21P,..Tru:.~$~ Site: PB Z Pad Vertical (TVD) Reference: 54+28.582.5 WeU: Plan Z-210 Sectiøo(\'S)Jlefere..~: . .... Well(0.OON,0.OOE,89;~~1) WêDpath: Plan Z-210 SlIrvey Calculatio.. Method: Minimum Curvature Db: oracle SlIrvey loci Azim TVD Sys TVD N/S MapE deg <:leg ft ft ft ft 4475.00 44.11 106.60 3254.10 3171.60 602.71 2495.05 4.00 5959995.50 601581.67 MWD 4500.00 43.80 107.97 3272.10 3189.60 597.55 2511.62 4.00 5959990.56 601598.30 MWD 4525.00 43.50 109.36 3290.19 3207.69 592.03 2527.97 4.00 5959985.26 601614.72 MWD 4533.48 43.40 109.83 3296.35 3213.85 590.07 2533.46 4.00 5959983.38 601620.23 End Dir : 4533 4550.00 43.40 109.83 3308.35 3225.85 586.22 2544.14 0.00 5959979.67 601630.96 MWD 4575.00 43.40 109.83 3326.51 3244.01 580.40 2560.30 0.00 5959974.05 601647.20 MWD 4600.00 43.40 109.83 3344.68 3262.18 574.57 2576.46 0.00 5959968.44 601663.43 MWD 4625.00 43.40 109.83 3362.84 3280.34 568.74 2592.62 0.00 5959962.83 601679.66 MWD 4650.00 43.40 109.83 3381.00 3298.50 562.91 2608.78 0.00 5959957.21 601695.90 MWD 4675.00 43.40 109.83 3399.17 3316.67 557.09 2624.94 0.00 5959951.60 601712.13 MWD 4700.00 43.40 109.83 3417.33 3334.83 551.26 2641.10 0.00 5959945.99 601728.37 MWD 4725.00 43.40 109.83 3435.49 3352.99 545.43 2657.26 0.00 5959940.37 601744.60 MWD 4748.41 43.40 109.83 3452.50 3370.00 539.98 2672.39 0.00 5959935.12 601759.80 UG3 4750.00 43.40 109.83 3453.66 3371.16 539.61 2673.42 0.00 5959934.76 601760.83 MWD 4775.00 43.40 109.83 3471.82 3389.32 533.78 2689.58 0.00 5959929.15 601777.07 MWD 4800.00 43.40 109.83 3489.98 3407.48 527.95 2705.74 0.00 5959923.54 601793.30 MWD 4825.00 43.40 109.83 3508.15 3425.65 522.13 2721.90 0.00 5959917.92 601809.54 MWD 4850.00 43.40 109.83 3526.31 3443.81 516.30 2738.06 0.00 5959912.31 601825.77 MWD 4875.00 43.40 109.83 3544.47 3461.97 510.47 2754.22 0.00 5959906.70 601842.00 MWD 4900.00 43.40 109.83 3562.64 3480.14 504.64 2770.38 0.00 5959901.08 601858.24 MWD 4925.00 43.40 109.83 3580.80 3498.30 498.82 2786.54 0.00 5959895.47 601874.47 MWD 4950.00 43.40 109.83 3598.96 3516.46 492.99 2802.70 0.00 5959889.86 601890.71 MWD 4975.00 43.40 109.83 3617.12 3534.62 487.16 2818.86 0.00 5959884.24 601906.94 MWD 5000.00 43.40 109.83 3635.29 3552.79 481.34 2835.02 0.00 5959878.63 601923.17 MWD 5025.00 43.40 109.83 3653.45 3570.95 475.51 2851.18 0.00 5959873.02 601939.41 MWD 5050.00 43.40 109.83 3671.61 3589.11 469.68 2867.34 0.00 5959867.41 601955.64 MWD 5075.00 43.40 109.83 3689.78 3607.28 463.85 2883.50 0.00 5959861.79 601971.88 MWD 5100.00 43.40 109.83 3707.94 3625.44 458.03 2899.66 0.00 5959856.1 I) 601988.11 MWD 5125.00 43.40 109.83 3726.10 3643.60 452.20 2915.82 0.00 5959850.57 602004.34 MWD 5150.00 43.40 109.83 3744.27 3661.77 446.37 2931.98 0.00 5959844.95 602020.58 MWD 5175.00 43.40 109.83 3762.43 3679.93 440.55 2948.14 0.00 5959839.34 602036.81 MWD 5200.00 43.40 109.83 3780.59 3698.09 434.72 2964.30 0.00 5959833.73 602053.05 MWD 5225.00 43.40 109.83 3798.76 3716.26 428.89 2980.46 0.00 5959828.11 602069.28 MWD 5250.00 43.40 109.83 3816.92 3734.42 423.06 2996.62 0.00 5959822.50 602085.51 MWD 5275.00 43.40 109.83 3835.08 3752.58 417.24 3012.78 0.00 5959816.89 602101.75 MWD 5300.00 43.40 109.83 3853.25 3770.75 411.41 3028.94 0.00 5959811.28 602117.98 MWD 5325.00 43.40 109.83 3871.41 3788.91 405.58 3045.10 0.00 5959805.66 602134.22 MWD 5350.00 43.40 109.83 3889.57 3807.07 399.76 3061.26 0.00 5959800.05 602150.45 MWD 5375.00 43.40 109.83 3907.74 3825.24 393.93 3077.42 0.00 5959794.44 602166.68 MWD 5400.00 43.40 109.83 3925.90 3843.40 388.10 3093.58 0.00 5959788.82 602182.92 MWD 5425.00 43.40 109.83 3944.06 3861.56 382.27 3109.74 0.00 5959783.21 602199.15 MWD 5436.61 43.40 109.83 3952.50 3870.00 379.57 3117.25 0.00 5959780.60 602206.69 UG1 5450.00 43.40 109.83 3962.22 3879.72 376.45 3125.90 0.00 5959777.60 602215.39 MWD 5475.00 43.40 109.83 3980.39 3897.89 370.62 3142.06 0.00 5959771.98 602231.62 MWD 5500.00 43.40 109.83 3998.55 3916.05 364.79 3158.22 0.00 5959766.37 602247.85 MWD 5525.00 43.40 109.83 4016.71 3934.21 358.97 3174.38 0.00 5959760.76 602264.09 MWD 5550.00 43.40 109.83 4034.88 3952.38 353.14 3190.54 0.00 5959755.15 602280.32 MWD 5575.00 43.40 109.83 4053.04 3970.54 347.31 3206.70 0.00 5959749.53 602296.55 MWD 5600.00 43.40 109.83 4071.20 3988.70 341 .49 3222.86 0.00 5959743.92 602312.79 MWD 5625.00 43.40 109.83 4089.37 4006.87 335.66 3239.02 0.00 5959738.31 602329.02 MWD 5650.00 43.40 109.83 4107.53 4025.03 329.83 3255.18 0.00 5959732.69 602345.26 MWD 5675.00 43.40 109.83 4125.69 4043.19 324.00 3271.34 0.00 5959727.08 602361.49 MWD 5700.00 43.40 109.83 4143.86 4061.36 318.18 3287.50 0.00 5959721.47 602377.72 MWD , ... . . BP BP Planning Report Company: BP Amoco Date: 8/2512004 .TÙti: .t6:12:53.·.. ..... .).yy"ame: 4 Field: Prudhoe Co-ordina~) .Reference: Well:Plan.:Z-210. T~ NOì'tt) Site: PBZPad Vertic:al (TVD)Reference: 54+28.582.5 WeD: Plan.Z-210 Section (VS)Reference: Well (0.OON,O.O()E,89.:i5AZi) WeDpath: Plan Z-21 0 Survey CalcnlatiOu MetI1od: Minimum Curvature D): Or$cle Survey MD Ine! ADm TVD SysTVD N/S lJW DLS ft deg deg ft ft ft ft deg/100ft 5725.00 43.40 109.83 4162.02 4079.52 312.35 3303.66 0.00 5959715.85 602393.96 MWD 5750.00 43.40 109.83 4180.18 4097.68 306.52 3319.82 0.00 5959710.24 602410.19 MWD 5775.00 43.40 109.83 4198.35 4115.85 300.70 3335.98 0.00 5959704.63 602426.43 MWD 5794.48 43.40 109.83 4212.50 4130.00 296.15 3348.57 0.00 5959700.25 602439.08 Ma 5800.00 43.40 109.83 4216.51 4134.01 294.87 3352.14 0.00 5959699.02 602442.66 MWD 5825.00 43.40 109.83 4234.67 4152.17 289.04 3368.30 0.00 5959693.40 602458.89 MWD 5850.00 43.40 109.83 4252.84 4170.34 283.21 3384.46 0.00 5959687.79 602475.13 MWD 5870.18 43.40 109.83 4267.50 4185.00 278.51 3397.50 0.00 5959683.26 602488.24 Mb1 5875.00 43.40 109.83 4271.00 4188.50 277.39 3400.62 0.00 5959682.18 602491.36 MWD 5900.00 43.40 109.83 4289.16 4206.66 271.56 3416.78 0.00 5959676.56 602507.60 MWD 5925.00 43.40 109.83 4307.32 4224.82 265.73 3432.94 0.00 5959670.95 602523.83 MWD 5945.89 43.40 109.83 4322.50 4240.00 260.86 3446.44 0.00 5959666.26 602537.39 Mb2 5950.00 43.40 109.83 4325.49 4242.99 259.91 3449.10 0.00 5959665.34 602540.06 MWD 5975.00 43.40 109.83 4343.65 4261.15 254.08 3465.26 0.00 5959659.72 602556.30 MWD 6000.00 43.40 109.83 4361.81 4279.31 248.25 3481.42 0.00 5959654.11 602572.53 MWD 6025.00 43.40 109.83 4379.98 4297.48 242.42 3497.58 0.00 5959648.50 602588.77 MWD 6035.35 43.40 109.83 4387.50 4305.00 240.01 3504.27 0.00 5959646.17 602595.49 Me 6050.00 43.40 109.83 4398.14 4315.64 236.60 3513.74 0.00 5959642.89 602605.00 MWD 6075.00 43.40 109.83 4416.30 4333.80 230.77 3529.90 0.00 5959637.27 602621.23 MWD 6100.00· 43.40 109.83 4434.47 4351.97 224.94 3546.06 0.00 5959631.66 602637.47 MWD 6124.82 43.40 109.83 4452.50 4370.00 219.16 3562.10 0.00 5959626.09 602653.59 Na 6125.00 43.40 109.83 4452.63 4370.13 219.12 3562.22 0.00 5959626.05 602653.70 MWD 6150.00 43.40 109.83 4470.79 4388.29 213.29 3578.38 0.00 5959620.43 602669.94 MWD 6159.23 43.40 109.83 4477.50 4395.00 211.14 3584.34 0.00 5959618.36 602675.93 Nb 6175.00 43.40 109.83 4488.96 4406.46 207.46 3594.54 0.00 5959614.82 602686.17 MWD 6200.00 43.40 109.83 4507.12 4424.62 201.63 3610.70 0.00 5959609.21 602702.40 MWD 6221.17 43.40 109.83 4522.50 4440.00 196.70 3624.38 0.00 5959604.45 602716.15 Nc 6225.00 43.40 109.83 4525.28 4442.78 195.81 3626.86 0.00 5959603.59 602718.64 MWD 6250.00 43.40 109.83 4543.45 4460.95 189.98 3643.02 0.00 5959597.98 602734.87 MWD 6275.00 43.40 109.83 4561.61 4479.11 184.15 3659.18 0.00 5959592.37 602751.11 MWD 6300.00 43.40 109.83 4579.77 4497.27 178.33 3675.34 0.00 5959586.76 602767.34 MWD 6325.00 43.40 109.83 4597.94 4515.44 172.50 3691.50 0.00 5959581.14 602783.57 MWD 6350.00 43.40 109.83 4616.10 4533.60 166.67 3707.66 0.00 5959575.53 602799.81 MWD 6365.69 43.40 109.83 4627.50 4545.00 163.01 3717.80 0.00 5959572.01 602810.00 Z-210A T1 6375.00 43.03 109.90 4634.28 4551.78 160.85 3723.79 4.00 5959569.92 602816.02 MWD 6400.00 42.04 110.08 4652.70 4570.20 155.07 3739.68 4.00 5959564.35 602831.98 MWD 6425.00 41.05 110.27 4671.41 4588.91 149.35 3755.24 4.00 5959558.84 602847.61 MWD 6439.64 40.47 110.38 4682.50 4600.00 146.04 3764.20 4.00 5959555.64 602856.62 Z-210 Fault 2 6446.20 40.21 110.44 4687.50 4605.00 144.55 3768.18 4.00 5959554.21 602860.61 OBa 6450.00 40.06 110.47 4690.41 4607.91 143.70 377Q.48 4.00 5959553.39 602862.92 MWD 6475.00 39.07 110.67 4709.68 4627.18 138.10 3785.39 4.00 5959547.99 602877.90 MWD 6485.04 38.67 110.76 4717.50 4635.00 135.87 3791.28 4.00 5959545.84 602883.82 OBb 6500.00 38.08 110.89 4729.23 4646.73 132.57 3799.96 4.00 5959542.66 602892.55 MWD 6525.00 37.09 111.11 4749.04 4666.54 127.11 3814.20 4.00 5959537.38 602906.85 MWD 6541.80 36.42 111.27 4762.50 4680.00 123.48 3823.57 4.00 5959533.87 602916.27 OBc 6550.00 36.10 111.35 4769.11 4686.61 121.71 3828.09 4.00 5959532.17 602920.81 MWD 6575.00 35.11 111.59 4789.44 4706.94 116.39 3841.63 4.00 5959527.02 602934.42 MWD 6600.00 34.12 111.85 4810.01 4727.51 111.13 3854.82 4.00 5959521.94 602947.68 MWD 6615.03 33.52 112.02 4822.50 4740.00 108.01 3862.58 4.00 5959518.92 602955.48 OBd 6625.00 33.13 112.13 4830.83 4748.33 105.95 3867.66 4.00 5959516.93 602960.58 MWD 6650.00 32.14 112.41 4851.88 4769.38 100.84 3880.13 4.00 5959511.98 602973.12 MWD 6675.00 31.15 112.72 4873.17 4790.67 95.81 3892.25 4.00 5959507.11 602985.30 MWD , ò' ,. . . BP BP Planning Report çOlnpany: BP Amoco Field: Prudhoe Bay Site: PB ZPad WeD: PléJO.z-210 WeUpath: Plan Z-21 0 Survey MD Inel Azim TVD $ytTVD N/S EIW ft deg deg ft ft ft 6691.69 30.49 112.93 4887.50 4805.00 92.49 3900.13 4.00 6700.00 30.17 113.04 4894.67 4812.17 90.85 3903.99 4.00 6725.00 29.18 113.38 4916.39 4833.89 85.98 3915.37 4.00 6731.99 28.91 113.48 4922.50 4840.00 84.63 3918.48 4.00 6750.00 28.20 113.74 4938.32 4855.82 81.18 3926.37 4.00 6775.00 27.21 114.13 4960.46 4877.96 76.46 3936.99 4.00 5959488.36 603030.29 MWD 6782.91 26.90 114.26 4967.50 4885.00 74.99 3940.27 4.00 5959486.93 603033.59 OBCBase 6800.00 26.23 114.54 4982.79 4900.29 71.83 3947.23 4.00 5959483.86 603040.59 MWD 6825.00 25.25 114.99 5005.31 4922.81 67.28 3957.09 4.00 5959479.45 603050.51 MWD 6828.61 25.11 115.05 5008.57 4926.07 66.63 3958.48 4.00 5959478.82 603051.91 End Dir : 6828 6850.00 25.11 115.05 5027.94 4945.44 62.79 3966.71 0.00 5959475.08 603060.18 MWD 6875.00 25.11 115.05 5050.58 4968.08 58.30 3976.31 0.00 5959470.72 603069.85 MWD 6900.00 25.11 115.05 5073.22 4990.72 53.81 3985.92 0.00 5959466.35 603079.51 MWD 6925.00 25.11 115.05 5095.86 5013.36 49.31 3995.53 0.00 5959461.99 603089.18 MWD 6947.00 25.11 115.05 5115.78 5033.28 45.36 4003.99 0.00 5959458.15 603097.69 7" 6947.80 25.11 115.05 5116.50 5034.00 45.22 4004.30 0.00 5959458.01 603098.00 Z-210A T2 . . Winton, The plug back hole will be cemented in two stages, each stage being 900' in length. Cement volume will be based on openhole volume plus 30 % excess. Each stage will be 87 bbls of cement, for a total of 174 bbls. The planned TOe is 6,116' MD. Regards, Rob Tirpack 564-4166 office 440-8633 cell tirpacrb(â2bp.com TERRIE L HUBBLE BP EXPLORATION AK INC POBOX 196612 MB7-5 ANCHORAGE, AK 99519-6612 143 252 89-6/ Mastercard Check DATE $ PAY TO THE OROER OF l \, ..' II /:\ i() !) "'-- ,t"l . ". First 'National Bank Alaska Anchorage, AK 99501 - . -00 LtARS .55/;,,· 0.~3 II /;227 II qq.~ ,. . ~ ': . 25 2000 /;0 MEMO . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /itA i!-2/o/J , PTD# 2oC¡-/~/ Development >< Service ~ Exploration Stratigraphic CHECKWßAT ADD-ONS ~'CLUE". APPLIES (OPTIONS) MULTI The permit is for a new wenbore segment of LATERAL existing wen . 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 60-69) above. PILOT HOLE In accordance witb 20 AAC 25.005(f), aU (PH) records, data and logs acquired for tbe pilot )< bole must be dearly differentiated In both .;.ame (name on permit plus PH) -.2Ið; and API num ber (50 02-"- 2- 7~ from records, data and Jogs acquired for well (name on permit). SPACING The permit is approved subject ·to fuD EXCEPTION .. compliance witb 20 AAC 25.0S5~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing e:J ception. (Company Name) assumes the liability of any prot est to tbe spacing .e:Jception tbat may occur. DRY DITCH AU dry ditch sample sets submitted to tbe SAMPLE Commission must be in no greater ·tban 30' sample intervals from below tbe permafrost or from where samples are first caught and ] 0' sample h:iter:vaJs through target zones. .. "3~<-~ e - D Well bore seg Annular Disposal Program SER On/Off Shore On PRUDHOE SAY, ORION SCHR BL OIL - 640135 Well Name: PRUDHOE BAY UN ORIN 2-21 Oi ALASKA) INC Initial ClasslType _SER 11WINJ GeoArea Unit Administration P~rmit fee attache_d - - - - - - - - - - - - - - - - - - - _ Y_es - - - - - - - - - - - - - - - - - - - - 12 _Leas_e_number _appropri<lte_ _ _ _ _ - - - - - - - - - - - _. - - Y~s_ - - - - - - - - - - - - -- 3 _U_nlqueweltn_am~_a!ld Ol!rnb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - Y~s__ - - - - - - - - - - - - - - - - - - - - 4 We.ll.loc<lt~d in_a defir¡e{Jpool_ . . _ _ _ - - - - - - - - - - - - .Yes _ - - - - -- 5 We.ll.loc<lt~d prpper _distance_ from driJling ur¡itbour¡dal)'_ _ _ _ _ _ _ . . _ _ _ _ _ _ . . . . .Yes - - - - - - - - - - - -- 6 WeUloc<lted prpper _distance from other welJs_ _ _ _ _ - - - - - - Y~s - - - - - - - - - - - 7 _S_utficier¡t <lcreageayail<lble in_dJilliog unjL _ _ _ _ _ _ _ _ . . _ _ _ . _ _ - Y~s - - - - - - - - - - - - - - 8 Jtdeviated, js_ wellbore plaUr¡cJu_ded _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ . _ .Yes - - - - - - - - 9 _Operator onlY' affected party _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ . . Y~s - - - - - - - - - - - - - - 10 _Operator has_apprppriate_b.ond inJorce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . - - - - - - - - Y~$ - - - - - ~ - - - - - - - - - - - - - - 11 Peunit c.a!l be iSSl!ed without co_nservation order_ - - - - - - - - - - - - - . _ .Yes - - - - - - - - - - - -- Appr Date 12 P~rrnit c.an be iSSl!ed without ad_ministratilleapprpval _ _ _ . _ _ - - - - - Y~s - - - - - - - - - - - -- RPC 9/16/2004 13 Can permit be approved before 15-day wait Yes 14 Wellloc<lted within area and_strata _authorized by Injection Order # (puUO# in_cpmmentsUFor Y~s .A.10-24 _ 15 AJI wel]sJI\(ithtn Jl4_mile_area_of review jdeotified (Fpr servjC!'!we[l onlY') _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s ~O~I; _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 16 Pre-produ.ced. i!ljector; {Jur<ltio_n_of pre-pro{JuG!ior¡ I~ss than.:3 months. (For service well only) . _NA - - - - - - - -- 17 _A{:MP finding 9f Con_si$te!lCY. has been Jssued_ forJhis project _ _NA - - - - - - - - - - - - - - - - - - - - Engineering 18 _C9!lductor stÖngpJov[ded _ _ _ _ _ - - - - - - - - _ _ _ _ Yes 20" @ 1 Q9'. _ _ _ - - - - - 19 Sudacecasing_pJotec_ts allknowl1 USDWs _ _ _ _ _ _ _ .Ye$ - - - - - - - 20 CMTvoladeql!ate_to circutate_on_cor¡d_uctor_& SUJtC$g _ - - - - - - - .Yes .A.de_quate excess, _ _ _ _ _ . 21 _CMT vol adeql!ateJo tie-in longstri!lg tosud csg_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ - - - - - - - - - - - - - - - - 22 CMTwill coyer.aJl kr¡ownpro_ductiye horizon_s_ - - - - - - - Y~s 23 _C_a$i!lg designs ad_e,!ua_te fpr CoT, B _&_ Rermafros! - - - - - - - - - - - Y~s - - - - - - - - - - - 24 _A{Jequ<ltetan_kage_oJ re_serve pit _ _ _ _ _ _ _ _ _ _ _ _ _ - - - Y~s ~ab.o[S7ES, _ _ _ _ _ . _ _ 25 ItaJEH(iII~ hasa 10-403 for øbandol1rneÐt be~n <lPPJoved . NA ~ewwell, _ _ . 26 _Mequ<lte well bore ~eparatjoÐ _proposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _Y_es - - - - - - - - - - - - - -. - - - -- 27 I(dive(ter Jeq_uiJ~d, does itrneet regulations_ _ . . . . . _ _ _ _ _ Yes - - - - - - - - - - Appr Date 28 _DJilling fJuid_Rrogram sGhematic_& e<tuipJis!adequ<lte_ _ . . _ . _ _ . . - - .Y~s Max MW9,Q ppg._ . WGA 9/16/2004 29 _BOPEs,_doJhey.rneetJegulatior¡ _ . . . . _ _ _ _ _ _ _ _ . _ _. - Y~s - - - - - - - 30 _SOPE.press ratiog appropriate;_test to_(puJ psig Lncommer¡tsL _ _ _ ... Y~s T~st to 4000_ psi. _MSF> 1724 psi._ 31 _C_hoke_manifold complies. w/APt RF>-5:3 (May 84)_ . .. - Y~s - - - - - - - - 32 Work will OCCU( withOlJtoperation _shutdown . _ _ _ _ _ _ _ _ . - - Y~s - - - - - - 33 Is. presence of H2S gas_prQb_able _ . _ _ . . . . _ _ _ _ _ _ _ _ _ .. _ No_ NoLa!l H2S pad. . 34 MeclJa_n[caU:or¡djt[o!l p{ w~lIs within .A.OR verified. (for_ s_ervjce welJ only) _ _ _ Yes ~o wells witlJio AOR. Geology 35 P~rmit c.a!l be iSSl!ed w/o hydrogen_ s_ulfide meaSJJ(eS _ _ _ _ . _ . - . . Y~s 36 _D_ata.PJesented. on_ pote_ntial oveJpres.sure _ZOne$ _ _ _ _ _ _ _ _ NA Appr Date 137 _S~Lsmic_analysjs. of shallow gas_zpnes_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ .NA RPC 9/16/2004 38 _S~abedcondition Sl!rvey _(if off-sh_o(e) . _NA - - - - -- 39 _ Conta_ct na.rnelphoneJor_weekly progre~ueports [eJ<ploratOl)'o!lIYI- .. _NA - - G,olog;, ~ Engineering Date Date Commissioner: Dat . , Commissioner: Ortginal Signed ~ j ( DAN SEAMOUNT . e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infomlation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. J . . ,~ð ?.f-- / 9 ( Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Feb 22 14:01:08 2005 l)~ì~ it Reel Header Service name... ..... .....LISTPE Date........ . . . .. .. . . . . . .05/02/22 Origin................. ..STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name.......UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name........... ..LISTPE Date...... . . . . . . . . . . . .. . .05/02/22 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name..... . .UNKNOWN Comments. ................STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA Z-210 500292322600 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 22-FEB-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 MW0003328880 B. HENNINGSE A. MADSEN MWDRUN 2 MW0003328880 B. HENNINGSE A. MADSEN MWDRUN 3 MW0003328880 B. HENNINGSE A. MADSEN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 4 MW0003328880 P. SMITH D. FERGUSON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 19 11N 12E 4565 3578 81.90 52.20 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 12.250 8.750 CASING SIZE (IN) 20.000 9.625 DRILLERS DEPTH (FT) 109.0 3811.0 # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. . . THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE EXITS Z-210 PB1 AT 3957'MD/2855'TVD BY MEANS OF AN OPENHOLE SIDETRACK. 4. MWD RUNS 1 & 2 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR) , UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. MWD RUNS 3 & 4 COMPRISED DIRECTIONAL; DGR; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); PRESSURE-WHILE-DRILLING (PWD); COMPENSATED THERMAL NEUTRON POROSITY (CTN); STABILIZED LITHO-DENSITY (SLD); AND ACOUSTIC CALIPER (ACAL). 6. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED- HOLE GAMMA RAY LOG RUN ON 30 OCTOBER 2004 IN THE Z-210 WELLBORE. THESE DIGITAL DATA WERE PROVIDED BY W. TIFENTAL (SIS/BP) VIA E-MAIL ON 21 JANUARY 2005. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. 7. MWD RUNS 1 - 4 REPRESENT WELL Z-210 WITH API#: 50-029-23226-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 6958'MD/5118'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, ACAL-DERIVED HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: ACAL-DERIVED (8.75" BIT) MUD WEIGHT: 9.0 - 9.2 PPG MUD SALINITY: 400 PPM CHLORIDES FORMATION WATER SALINITY: 15,000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name.............STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......05/02/22 Maximum Physical Record..65535 . . File Type. ...............LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP NCNT NPHI FCNT RPX RPS RPM RPD FET DRHO RHOB PEF $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 543.5 589.0 3743.0 3743.5 3743.5 3792.0 3792.0 3792.0 3792.0 3792.0 3811.0 3811.0 3811.0 STOP DEPTH 6931.0 6968.5 6874.0 6873.5 6874.5 6923.5 6923.5 6923.5 6923.5 6923.5 6887.0 6887.0 6887.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 543.5 4514.5 4525.5 4530.5 4534.0 4544.5 4556.0 4574.5 4579.5 4583.5 4590.0 4595.0 4609.0 4615.5 4620.5 4629.0 4632.5 4636.5 4648.5 4655.0 4666.0 4668.0 4679.0 4686.0 4698.0 4704.0 4708.5 4713.5 4732.5 4741.0 4751.5 4760.0 4765.0 4779.0 4793.5 4795.0 4802.5 4818.0 4824.0 4827.5 4833.0 4836.0 4853.0 4858.5 4869.5 GR 539.0 4510.0 4522.0 4526.0 4529.5 4539.0 4551. 5 4569.5 4573.0 4578.0 4582.5 4586.5 4602.5 4609.0 4614.0 4623.0 4626.5 4630.5 4642.0 4648.0 4659.0 4662.0 4672.0 4679.0 4689.0 4697.0 4702.5 4708.0 4725.0 4733.5 4744.0 4752.5 4758.0 4773.0 4785.0 4787.0 4795.0 4809.5 4816.5 4819.5 4825.0 4827.5 4845.5 4852.0 4863.5 4878.0 4882.5 4890.5 4896.0 4920.0 4924.0 4930.5 4939.5 4943.5 4960.0 4968.0 4988.5 5008.5 5041. 0 5048.5 5065.5 5080.5 5090.0 5107.5 5119.5 5122.0 5126.0 5152.5 5177.5 5190.5 5194.5 5214.5 5241. 0 5253.5 5277.0 5279.5 5296.5 5309.0 5326.5 5335.5 5352.5 5361. 0 5372.0 5376.5 5386.0 5395.5 5416.5 5422.5 5427.0 5448.0 5456.0 5463.5 5485.0 5500.5 5509.5 5520.0 5573.0 5588.0 5604.0 5612.5 5616.0 5621.5 5624.0 5641.0 5643.0 5663.5 5669.5 5673 .5 5679.5 5694.5 5703.5 5710.0 5715.5 5718.5 5721.5 5735.5 5745.5 5757.5 5784.5 5786.0 5798.0 . . 4871.0 4874.5 4883.5 4889.0 4914.0 4917.0 4924.0 4931.5 4936.5 4953.0 4961.0 4982.5 5002.0 5036.0 5041. 5 5059.5 5073.5 5083.5 5101.5 5112.0 5115.5 5119.5 5147.0 5172.5 5184.5 5188.0 5206.0 5233.0 5245.5 5269.0 5271.5 5288.5 5301.0 5319.5 5327.5 5344.5 5354.0 5364.0 5369.0 5377.0 5388.0 5409.0 5414.0 5419.5 5440.5 5449.0 5458.0 5475.0 5489.5 5499.5 5510.5 5565.0 5579.0 5596.5 5604.5 5607.5 5614.0 5616.5 5633.0 5634.5 5656.0 5661. 0 5665.0 5670.5 5686.0 5694.5 5702.0 5707.0 5709.5 5714.0 5727.0 5738.0 5749.0 5775.5 5777.0 5789.0 . . 5807.0 5820.0 5824.5 5848.5 5863.5 5868.0 5897.0 5899.5 5903.0 5905.5 5907.5 5911.0 5918.5 5933.0 5950.0 5952.5 5959.5 5967.5 5970.0 5986.5 5989.0 5995.0 6002.5 6016.0 6026.0 6028.0 6041.0 6048.5 6059.5 6074.0 6086.5 6118.5 6122.5 6125.5 6131. 5 6141. 5 6143.5 6155.5 6157.0 6163.0 6174.0 6183.0 6187.5 6195.0 6211.5 6223.0 6228.0 6260.0 6280.0 6287.5 6306.0 6338.5 6368.5 6411.0 6415.0 6427.5 6447.0 6470.0 6484.0 6490.0 6497.5 6502.0 6541. 5 6560.0 6579.5 6599.0 6628.5 6645.0 6673.5 6690.5 6701.0 6712.0 6715.5 6725.0 6968.5 $ 5797.5 5810.5 5815.0 5838.5 5854.0 5858.0 5888.0 5890.5 5893.5 5896.5 5898.5 5901.0 5908.0 5923.5 5941.0 5944.0 5951.5 5958.0 5961.5 5977.0 5980.0 5986.0 5994.0 6006.0 6018.0 6019.5 6031.5 6039.0 6051.0 6064.0 6077.5 6110.5 6114.0 611 7.0 6123.0 6132.5 6135.0 6144.5 6146.0 6152.5 6166.5 6173 . 5 6179.0 6186.0 6202.5 6214.0 6219.5 6249.0 6270.0 6275.5 6295.5 6328.0 6359.0 6401.0 6404.5 6416.0 6436.5 6459.5 6474.0 6480.5 6488.0 6492.0 6530.5 6550.0 6569.0 6589.0 6617.0 6633.5 6664.5 6681. 5 6690.0 6702.0 6706.0 6714.5 6958.0 . . # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ BIT RUN NO 1 2 3 4 MERGE TOP 539.0 2173.0 3831. 0 3957.0 MERGE BASE 2173.0 3831. 0 3957.0 6958.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type........... . . .....0 Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units. . . . . . . . . . . Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record.. . . . . . . . . . . .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 543.5 6968.5 3756 12851 543.5 6968.5 ROP MWD FT/H 6.2 1411.41 250.671 12760 589 6968.5 GR MWD API 14.09 139.68 72.3127 12776 543.5 6931 RPX MWD OHMM 1. 28 2000 10.5861 6264 3792 6923.5 RPS MWD OHMM 0.06 1182.99 10.5137 6264 3792 6923.5 RPM MWD OHMM 0.82 2000 11.5498 6264 3792 6923.5 RPD MWD OHMM 0.46 2000 15.4539 6264 3792 6923.5 FET MWD HOUR 0.08 202.46 8.00838 6264 3792 6923.5 NPHI MWD PU-S 15.71 88.28 35.6866 6261 3743.5 6873.5 FCNT MWD CNTS 491 1984 940.309 6263 3743.5 6874.5 NCNT MWD CNTS 113000 180816 137718 6263 3743 6874 RHOB MWD G/CM 1.337 3.252 2.22554 6153 3811 6887 DRHO MWD G/CM -0.121 0.962 0.0655667 6153 3811 6887 PEF MWD BARN 0.39 1. 93 1.15121 6153 3811 6887 First Reading For Entire File.. ........543.5 Last Reading For Entire File.......... .6968.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation. . . . . . .05/02/22 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Next File Name.. ....... ..STSLIB.002 Physical EOF . File Header Service name. . . . . . . . . . . . .STSLIB.002 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/02/22 Maximum Physical Record. .65535 File Type........ ....... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 . header data for each bit run in separate files. 1 .5000 START DEPTH 539.0 584.5 STOP DEPTH 2127.5 2173 . 0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type......... .........0 Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . .Down Optical log depth units.......... .Feet 1l-OCT-04 Insite 66.37 Memory 2173.0 584.0 2173.0 .7 57.6 TOOL NUMBER 149206 12.250 109.0 Spud Mud 9.00 300.0 9.5 400 9.8 .000 .000 .000 .000 .0 75.2 .0 .0 . . Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value...... . . . . . . . . . . . . . . . . - 999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD010 GR MWD010 Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Nsam Rep 1 68 1 68 1 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 539 2173 1356 3269 539 2173 ROP MWD010 FT/H 10.62 678.99 163.751 3178 584.5 2173 GR MWD010 API 19.17 138.78 67.3119 3178 539 2127.5 First Reading For Entire File..........539 Last Reading For Entire File...........2173 File Trailer Service name. . . .... .. ... .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. .....05/02/22 Maximum Physical Record..65535 File Type. . . . . . . . . . . . . . . .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/02/22 Maximum Physical Record. .65535 File Type...... . . . . . . . . . .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 2128.0 2173.5 STOP DEPTH 3786.0 3831. 0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 12-0CT-04 Insite 66.37 Memory 3831. 0 2173.0 3831. 0 52.2 59.8 # TOOL STRING (TOP TO BOTTOM) . VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . .Down Optical log depth units...... .....Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value........... . . . . . . . . . . . - 999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD020 GR MWD020 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code . TOOL NUMBER 149206 12.250 109.0 Spud Mud 9.30 300.0 9.0 250 9.4 .000 .000 .000 .000 .0 78.8 .0 .0 Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2128 3831 2979.5 3407 2128 3831 ROP MWD020 FT/H 6.8 1411.41 306.151 3316 2173.5 3831 GR MWD020 API 14.43 124.72 77 . 0901 3317 2128 3786 First Reading For Entire File...... ... .2128 Last Reading For Entire File........ ...3831 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......05/02/22 Maximum Physical Record..65535 File Type... .............LO Next File Name...........STSLIB.004 Physical EOF File Header . Service name.............STSLIB.004 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/02/22 Maximum Physical Record..65535 File Type...... . . . . . . . . . .LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NCNT FCNT NPHI GR RPS RPM FET RPX RPD PEF DRHO RHOB ROP $ 4 . header data for each bit run in separate files. 3 .5000 START DEPTH 3738.5 3739.0 3739.0 3786.5 3787.5 3787.5 3787.5 3787.5 3787.5 3806.5 3806.5 3806.5 3831.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 3957.0 3957.0 3957.0 3957.0 3957.0 3957.0 3957.0 3957.0 3957.0 3957.0 3957.0 3957.0 3957.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 SLD CTN $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 16 -OCT- 04 Insite 66.37 Memory 3957.0 3831.0 3957.0 52.7 60.7 TOOL NUMBER 53516 56933 161646 181190 8.750 3811.0 LSND 9.10 55.0 9.5 400 5.8 3.000 1.867 4.000 2.500 70.0 116.6 70.0 70.0 . . # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type...... ............0 Data Specification Block Type.....O Logging Direction......... ........Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record. ............Undefined Absent value........... . . . . . ., . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 NCNT MWD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3738.5 3957 3847.75 438 3738.5 3957 ROP MWD030 FT/H 160.02 805.96 491.105 252 3831. 5 3957 GR MWD030 API 28.17 109.63 66.3984 342 3786.5 3957 RPX MWD030 OHMM 3.85 2000 27.572 340 3787.5 3957 RPS MWD030 OHMM 0.06 1182.99 29.6578 340 3787.5 3957 RPM MWD030 OHMM 5.79 2000 41.4962 340 3787.5 3957 RPD MWD030 OHMM 0.46 2000 125.5 340 3787.5 3957 FET MWD030 HOUR 0.08 81.65 21.9798 340 3787.5 3957 NPHI MWD030 PU-S 32.16 60.88 42.3064 437 3739 3957 FCNT MWD030 CNTS 612 965 779.38 437 3739 3957 NCNT MWD030 CNTS 116013 139255 128788 438 3738.5 3957 RHOB MWD030 G/CM 1. 962 2.319 2.17903 302 3806.5 3957 DRHO MWD030 G/CM -0.022 0.187 0.0652483 302 3806.5 3957 PEF MWD030 BARN 1. 02 1.5 1. 25401 302 3806.5 3957 First Reading For Entire File......... .3738.5 Last Reading For Entire File.... .......3957 File Trailer Service name........ .....STSLIB.004 Service Sub Level Name. . . version Number...........1.0.0 Date of Generation. ......05/02/22 Maximum Physical Record. .65535 File Type............... .LO Next File Name..... ......STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name. . . Version Number.......... .1.0.0 . Date of Generation.......05/02/22 Maximum Physical Record..65535 File Type.... ............LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NPHI FCNT RPS PEF ROP RPX RPM RPD FET NCNT RHOB DRHO GR $ 5 . header data for each bit run in separate files. 4 .5000 START DEPTH 3950.5 3950.5 3957.5 3957.5 3957.5 3957.5 3957.5 3957.5 3957.5 3957.5 3957.5 3957.5 3957.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 SLD CTN $ STOP DEPTH 6863.0 6864.0 6913.0 6876.5 6958.0 6913.0 6913.0 6913.0 6913.0 6863.5 6876.5 6876.5 6920.5 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 25-0CT-04 Insite 66.37 Memory 6958.0 3957.0 6958.0 30.3 55.9 TOOL NUMBER 53516 56933 161646 181190 8.750 3811.0 Water 9.10 60.0 8.5 400 .0 Based 3.100 1.832 3.750 1.800 64.0 113.0 64.0 64.0 . . # REMARKS: $ # Data Format Specification Record Data Record Type....... ...........0 Data Specification Block Type.....O Logging Direction....... ........ ..Down Optical log depth units. ........ ..Feet Data Reference Point..... ........ .Undefined Frame Spacing.................... .60 .1IN Max frames per record... ....... ...Undefined Absent value... . . .. .. . . ......... .. -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 Rap MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 NPHI MWD040 PU-S 4 1 68 32 9 FCNT MWD040 CNTS 4 1 68 36 10 NCNT MWD040 CNTS 4 1 68 40 11 RHOB MWD040 G/CM 4 1 68 44 12 DRHO MWD040 G/CM 4 1 68 48 13 PEF MWD040 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3950.5 6958 5454.25 6016 3950.5 6958 ROP MWD040 FT/H 6.2 1010.91 255.718 6002 3957.5 6958 GR MWD040 API 14.09 139.68 72.6229 5927 3957.5 6920.5 RPX MWD040 OHMM 1. 28 155.95 9.59116 5912 3957.5 6913 RPS MWD040 OHMM 0.95 135.86 9.39569 5912 3957.5 6913 RPM MWD040 OHMM 0.82 153.84 9.81252 5912 3957.5 6913 RPD MWD040 OHMM 0.68 101.25 9.12293 5912 3957.5 6913 FET MWD040 HOUR 0.09 201.98 0.50179 5912 3957.5 6913 NPHI MWD040 PU-S 15.71 88.28 35.2094 5813 3950.5 6863 FCNT MWD040 CNTS 491 1984 951.882 5815 3950.5 6864 NCNT MWD040 CNTS 113000 180816 138362 5813 3957.5 6863.5 RHOB MWD040 G/CM 1.337 3.252 2.22744 5839 3957.5 6876.5 DRHO MWD040 G/CM -0.121 0.962 0.065449 5839 3957.5 6876.5 PEF MWD040 BARN 0.39 1. 93 1.1454 5839 3957.5 6876.5 First Reading For Entire File... .... ...3950.5 Last Reading For Entire File.... .... ...6958 File Trailer Service name............ .STSLIB.005 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/02/22 Maximum Physical Record. .65535 File Type..... . . . .. . . . . . .LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name............ .LISTPE Date.................... .05/02/22 Origin.................. .STS Tape Name............... . UNKNOWN Continuation Number. . .. . .01 Next Tape Name....... ....UNKNOWN · . Comments..... ............STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name. ............LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/02/22 Origin. . . . . ............. .STS Reel Name.. ..............UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments... ..............STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File . . ,¿;;bL/- /r ( Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Feb 22 13:18:24 2005 p(:) 1,1 Reel Header Service name.... ........ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/02/22 Origin. . . ....... ...... . . .STS Reel Name. . ............. .UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. ~ Scientific Technical Services Tape Header Service name....... ......LISTPE Date. ... . . . . . . . . .. .. . ... .05/02/22 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.. . . . . . . . . . . . . . . UNKNOWN Continuation Number. . . . . .01 Previous Tape Name. . . . . . .UNKNOWN Comments........ ........ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA Z-210PB1 500292322670 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 22-FEB-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003328880 B. HENNINGSE A. MADSEN MWD RUN 2 MW0003328880 B. HENNINGSE A. MADSEN MWDRUN 3 MW0003328880 B. HENNINGSE A. MADSEN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MAD RUN 3 MW0003328880 B. HENNINGSE A. MADSEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 19 11N 12E 4565 3578 81.90 52.20 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 12.250 8.750 CASING SIZE (IN) 20.000 9.625 DRILLERS DEPTH (FT) 109.0 3811.0 # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. . . THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. Z-210 EXITS THIS WELLBORE AT 3957'MD/2855'TVD BY MEANS OF AN OPENHOLE SIDETRACK. 4. MWD RUNS 1 & 2 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR) , UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. MWD RUN 3 COMPRISED DIRECTIONAL; DGR; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); PRESSURE-WHILE-DRILLING (PWD); COMPENSATED THERMAL NEUTRON POROSITY (CTN); STABILIZED LITHO-DENSITY (SLD); AND ACOUSTIC CALIPER (ACAL). MAD-PASS DATA WERE ACQUIRED AFTER RUN 3 OVER THE INTERVAL 7341'MD-6845'MD. THESE MAD DATA ARE INCLUDED IN THIS PRESENTATION. 6. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED- HOLE GAMMA RAY LOG RUN ON 30 OCTOBER 2004 IN THE Z-210 WELLBORE. THESE DIGITAL DATA WERE PROVIDED BY W. TIFENTAL (SIS/BP) VIA E-MAIL ON 21 JANUARY 2005. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. 7. MWD RUNS 1 - 3 REPRESENT WELL Z-210 PB1 WITH API#: 50-029-23226-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7900'MD/5149'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, ACAL-DERIVED HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: ACAL-DERIVED (8.75" BIT) MUD WEIGHT: 9.0 - 9.2 PPG MUD SALINITY: 400 PPM CHLORIDES FORMATION WATER SALINITY: 15,000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name............ .STSLIB.001 . . Service Sub Level Name... Version Number.. ........ .1.0.0 Date of Generation...... .05/02/22 Maximum Physical Record. .65535 File Type....... . . . . . . . . . LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP NCNT FCNT NPHI RPX RPS RPM RPD FET PEF RHOB DRHO $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 543.5 589.0 3743.0 3743.5 3743.5 3792.0 3792.0 3792.0 3792.0 3792.0 3811.0 3811.0 3811.0 STOP DEPTH 7867.0 7904.5 7810.0 7810.0 7809.5 7859.5 7859.5 7859.5 7859.5 7859.5 7823.5 7823.5 7823.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 543.5 3954.5 7904.5 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # REMARKS: GR 539.0 3950.0 7900.0 BIT RUN NO 1 2 3 MERGED MAIN PASS. $ MERGE TOP 539.0 2173.0 3831.0 MERGE BASE 2173.0 3831.0 7900.0 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.......... ...... .Down Optical log depth units.......... . Feet Data Reference Point............. .Undefined Frame Spacing..................... 60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD . . BARN 1 68 14 52 4 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 543.5 7904.5 4224 14723 543.5 7904.5 ROP MWD FT/H 6.8 1411.41 292.995 14632 589 7904.5 GR MWD API 12.72 149.53 72.6183 14648 543.5 7867 RPX MWD OHMM 1. 87 2000 10.2834 8136 3792 7859.5 RPS MWD OHMM 0.06 1182.99 10.3599 8136 3792 7859.5 RPM MWD OHMM 1.17 2000 11.2448 8136 3792 7859.5 RPD MWD OHMM 0.46 2000 14.146 8136 3792 7859.5 FET MWD HOUR 0.07 81.65 1. 22028 8136 3792 7859.5 NPHI MWD PU-S 11.78 89.81 36.778 8133 3743.5 7809.5 FCNT MWD CNTS 481 2663 935.555 8134 3743.5 7810 NCNT MWD CNTS 112385 178900 137482 8135 3743 7810 RHOB MWD G/CM 1. 266 3.336 2.2232 8026 3811 7823.5 DRHO MWD G/CM -0.134 0.555 0.0838611 8026 3811 7823.5 PEF MWD BARN 0.39 2.47 1.15737 8026 3811 7823.5 First Reading For Entire File......... .543.5 Last Reading For Entire File.......... .7904.5 File Trailer Service name. . . . . . . . . . .. .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation. . .... .05/02/22 Maximum Physical Record..65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.... .......STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......05/02/22 Maximum Physical Record..65535 File Type. .............. .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MAD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE NCNT FCNT NPHI PEF DRHO RHOB RPX FET RPD RPS RPM GR RAT $ # MERGED DATA SOURCE PBU TOOL CODE MWD $ 2 and clipped curves; all MAD runs merged using earliest passes. .5000 START DEPTH 6757.5 6757.5 6758.5 6768.0 6768.0 6768.0 6806.5 6806.5 6806.5 6806.5 6806.5 6810.5 6849.5 STOP DEPTH 7251.0 7251. 0 7250.5 7263.0 7263.0 7263.0 7300.5 7300.5 7300.5 7300.5 7300.5 7308.0 7345.5 MAD RUN NO. MAD PASS NO. MERGE TOP 3 1 3738.5 MERGE BASE 7900.0 . . # REMARKS: MERGED MAD PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction...... ...........Down Optical log depth units.......... .Feet Data Reference Point........ ......Undefined Frame Spacing............ ....... ..60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HOUR 4 1 68 28 8 NPHI MAD PU-S 4 1 68 32 9 FCNT MAD CNTS 4 1 68 36 10 NCNT MAD CNTS 4 1 68 40 11 RHOB MAD G/CM 4 1 68 44 12 DRHO MAD G/CM 4 1 68 48 13 PEF MAD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6757.5 7345.5 7051.5 1177 6757.5 7345.5 RAT MAD FT/H 1. 84 2832.07 179.337 993 6849.5 7345.5 GR MAD API 35.44 126.09 81.1617 996 6810.5 7308 RPX MAD OHMM 2.68 14.65 5.22357 989 6806.5 7300.5 RPS MAD OHMM 2.64 15.69 5.38085 989 6806.5 7300.5 RPM MAD OHMM 2.72 17.4 5.73637 989 6806.5 7300.5 RPD MAD OHMM 2.74 16.73 5.7361 989 6806.5 7300.5 FET MAD HOUR 7.79 15.5 11.8655 989 6806.5 7300.5 NPHI MAD PU-S 19.58 37.72 31.2785 985 6758.5 7250.5 FCNT MAD CNTS 931 2014 1166.3 988 6757.5 7251 NCNT MAD CNTS 137483 183592 149247 988 6757.5 7251 RHOB MAD G/CM 2.079 2.973 2.35669 991 6768 7263 DRHO MAD G/CM -0.088 0.239 0.0622916 991 6768 7263 PEF MAD BARN 0.45 1. 96 1.13607 991 6768 7263 First Reading For Entire File.. ........6757.5 Last Reading For Entire File... ....... .7345.5 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......05/02/22 Maximum Physical Record. .65535 File Type...... . . . ... ... .LO Next File Name..... ......STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... version Number.......... .1.0.0 Date of Generation...... .05/02/22 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO . Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 . header data for each bit run in separate files. 1 .5000 START DEPTH 539.0 584.5 STOP DEPTH 2127.5 2173.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction........... ......Down Optical log depth units..... ......Feet Data Reference Point........ ......Undefined Frame Spacing..................... 60 .1IN Max frames per record............ .Undefined Absent value.... . . . . . . . . . . . . . . . . . . - 999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ll-OCT- 04 Insite 66.37 Memory 2173.0 584.0 2173.0 .7 57.6 TOOL NUMBER 149206 12.250 109.0 Spud Mud 9.00 300.0 9.5 400 9.8 .000 .000 .000 .000 .0 75.2 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel . . DEPT ROP MWD010 GR MWD010 FT FT/H API 4 4 4 1 68 1 68 1 68 o 4 8 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 539 2173 1356 3269 539 2173 ROP MWD010 FT/H 10.62 678.99 163.751 3178 584.5 2173 GR MWD010 API 19.17 138.78 67.3119 3178 539 2127.5 First Reading For Entire File......... .539 Last Reading For Entire File.......... .2173 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation. . . . . . .05/02/22 Maximum Physical Record. .65535 File Type..... . . . . . . . . . . . LO Next File Name... ....... .STSLIB.004 Physical EOF File Header Service name....... ... ...STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/02/22 Maximum Physical Record. .65535 File Type........ . . . . . . . . LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 4 header data for each bit run in separate files. 2 .5000 START DEPTH 2128.0 2173.5 STOP DEPTH 3786.0 3831. 0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 12 -OCT- 04 Insite 66.37 Memory 3831.0 2173.0 3831. 0 52.2 59.8 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY TOOL NUMBER 149206 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 12.250 109.0 # . . BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Spud Mud 9.30 300.0 9.0 250 9.4 .000 .000 .000 .000 .0 78.8 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.......... ........0 Data Specification Block Type.....O Logging Direction................ .Down Optical log depth units.......... . Feet Data Reference Point............. .Undefined Frame Spacing..................... 60 .1IN Max frames per record............ .Undefined Absent value............ . . . . . . . . . . - 999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD020 GR MWD020 Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Nsam Rep 1 68 1 68 1 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2128 3831 2979.5 3407 2128 3831 ROP MWD020 FT/H 6.8 1411.41 306.151 3316 2173.5 3831 GR MWD020 API 14.43 124.72 77.0901 3317 2128 3786 First Reading For Entire File....... ...2128 Last Reading For Entire File.... ...... .3831 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/02/22 Maximum Physical Record. .65535 File Type. .............. .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name.... ........ .STSLIB.005 Service Sub Level Name. . . Version Number.. ........ .1.0.0 Date of Generation...... .05/02/22 Maximum Physical Record. .65535 File Type.... . . . .. . . . . . . .LO Previous File Name...... .STSLIB.004 . Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NCNT FCNT NPHI GR FET RPM RPM RPS RPX PEF RHOB DRHO ROP $ 5 . header data for each bit run in separate files. 3 .5000 START DEPTH 3738.5 3739.0 3739.0 3786.5 3787.5 3787.5 3787.5 3787.5 3787.5 3806.5 3806.5 3806.5 3831. 5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 SLD CTN $ STOP DEPTH 7805.5 7805.5 7805.0 7862.5 7855.0 7855.0 7855.0 7855.0 7855.0 7819.0 7819.0 7819.0 7900.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record 16-0CT-04 Insite 66.37 Memory 7900.0 3831.0 7900.0 52.7 60.7 TOOL NUMBER 53516 56933 161646 181190 8.750 3811.0 LSND 9.10 55.0 9.5 400 5.8 3.000 1.867 4.000 2.500 70.0 116.6 70.0 70.0 . . Data Record Type.. . . . .............0 Data Specification Block Type.....O Logging Direction..... ............Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing. . . . . . . . . . . . . . . . . . . . .60 .1IN Max frames per record.. .......... . Undefined Absent value.. . . . .. . . . . . . ..... . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name DEPT ROP GR RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO PEF Service Order MWD030 MWD030 MWD030 MWD030 MWD030 MWD030 MWD030 MWD030 MWD030 MWD030 MWD030 MWD030 MWD030 Units FT FT/H API OHMM OHMM OHMM OHMM HOUR PU-S CNTS CNTS G/CM G/CM BARN Size 4 4 4 4 4 4 4 4 4 4 4 4 4 4 Rep 68 68 68 68 68 68 68 68 68 68 68 68 68 68 Code Offset o 4 8 12 16 20 24 28 32 36 40 44 48 52 Channel 1 2 3 4 5 6 7 8 9 10 11 12 13 14 Nsam 1 1 1 1 1 1 1 1 1 1 1 1 1 1 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3738.5 7900 5819.25 8324 3738.5 7900 ROP MWD030 FT/H 44 908.5 338.106 8138 3831. 5 7900 GR MWD030 API 12.72 149.53 72.8674 8153 3786.5 7862.5 RPX MWD030 OHMM 1. 87 2000 10.2834 8136 3787.5 7855 RPS MWD030 OHMM 0.06 1182.99 10.3599 8136 3787.5 7855 RPM MWD030 OHMM 1.17 2000 11.2448 8136 3787.5 7855 RPD MWD030 OHMM 0.46 2000 14.146 8136 3787.5 7855 FET MWD030 HOUR 0.07 81. 65 1.22028 8136 3787.5 7855 NPHI MWD030 PU-S 11.78 89.81 36.778 8133 3739 7805 FCNT MWD030 CNTS 481 2663 935.555 8134 3739 7805.5 NCNT MWD030 CNTS 112385 178900 137482 8135 3738.5 7805.5 RHOB MWD030 G/CM 1. 266 3.336 2.2232 8026 3806.5 7819 DRHO MWD030 G/CM -0.134 0.555 0.0838611 8026 3806.5 7819 PEF MWD030 BARN 0.39 2.47 1.15737 8026 3806.5 7819 First Reading For Entire File......... .3738.5 Last Reading For Entire File.......... .7900 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......05/02/22 Maximum Physical Record..65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name. ...... ......STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. .....05/02/22 Maximum Physical Record..65535 File Type........... ... ..LO Previous File Name.. .....STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 . ' . RAW MAD Curves and log DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: # FILE SUMMARY VENDOR TOOL CODE NCNT FCNT NPHI PEF RHOB DRHO RPX RPS RPM RPD FET GR RAT $ . for each pass of each run in separate files. header data .5000 3 1 START DEPTH 6753.0 6753.0 6754.0 6763.5 6763.5 6763.5 6802.0 6802.0 6802.0 6802.0 6802.0 6806.0 6845.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 SLD CTN $ STOP DEPTH 7246.5 7246.5 7246.0 7258.5 7258.5 7258.5 7296.0 7296.0 7296.0 7296.0 7296.0 7303.5 7341.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type......... .........0 Data Specification Block Type.....O 16-0CT-04 Insite 66.37 Memory 7341.0 6845.0 7341.0 52.7 60.7 TOOL NUMBER 53516 56933 161646 181190 8.750 3811.0 LSND 9.10 55.0 9.5 400 5.8 3.000 .000 4.000 2.500 70.0 .0 70.0 70.0 . . Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units..... ......Feet Data Reference Point........ ......Undefined Frame Spacing.................... .60 .1IN Max frames per record.... .. . ..... . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name DEPT RAT GR RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO PEF Service Order MAD031 MAD031 MAD031 MAD031 MAD031 MAD031 MAD031 MAD031 MAD031 MAD031 MAD031 MAD031 MAD031 Units FT FT/H API OHMM OHMM OHMM OHMM HOUR PU-S CNTS CNTS G/CM G/CM BARN Size 4 4 4 4 4 4 4 4 4 4 4 4 4 4 Offset o 4 8 12 16 20 24 28 32 36 40 44 48 52 Channel 1 2 3 4 5 6 7 8 9 10 11 12 13 14 Rep 68 68 68 68 68 68 68 68 68 68 68 68 68 68 Code Nsam 1 1 1 1 1 1 1 1 1 1 1 1 1 1 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6753 7341 7047 1177 6753 7341 RAT MAD031 FT/H 1. 84 2832.07 179.337 993 6845 7341 GR MAD031 API 35.44 126.09 81.1617 996 6806 7303.5 RPX MAD031 OHMM 2.68 14.65 5.22357 989 6802 7296 RPS MAD031 OHMM 2.64 15.69 5.38085 989 6802 7296 RPM MAD031 OHMM 2.72 17.4 5.73637 989 6802 7296 RPD MAD031 OHMM 2.74 16.73 5.7361 989 6802 7296 FET MAD031 HOUR 7.79 15.5 11.8655 989 6802 7296 NPHI MAD031 PU-S 19.58 37.72 31.2785 985 6754 7246 FCNT MAD031 CNTS 931 2014 1166.3 988 6753 7246.5 NCNT MAD031 CNTS 137483 183592 149247 988 6753 7246.5 RHOB MAD031 G/CM 2.079 2.973 2.35669 991 6763.5 7258.5 DRHO MAD031 G/CM -0.088 0.239 0.0622916 991 6763.5 7258.5 PEF MAD031 BARN 0.45 1.96 1.13607 991 6763.5 7258.5 First Reading For Entire File......... .6753 Last Reading For Entire File.......... .7341 File Trailer Service name............ .STSLIB.006 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/02/22 Maximum Physical Record. .65535 File Type..... . . . . . . . . . . . LO Next File Name.. ........ .STSLIB.007 Physical EOF Tape Trailer Service name........... ..LISTPE Date.................... .05/02/22 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.............. ..UNKNOWN Continuation Number. . . .. .01 Next Tape Name. . .. . . . . .. . UNKNOWN Comments............. ....STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.......... ...LISTPE Date.................... .05/02/22 Origin. . . . . . . . . . . . . . . . . . .STS Reel Name...... .... ......UNKNOWN . I . . Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments..... ............STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File '%#UUI1t'ln,:o~ B I I I I I I I I I I I I I I I I Schlulberger Fluid Analysis on Bottomhole Samples BP Field: Prudhoe Bay Well:Z210PB1 CONFIDENTIAL Black Oil PVT Study Report Prepared for Mr. Greg Bernaski BP CONFIDENTiAl Standard Conditions Used: Pressure: 14.696 psia Temperature: 60°F Prepared by: Meisong Van Reviewed by: Joseph Manakalathil Schlumberger WCP Oilphase-DBR 16223 Park Row, Suite 170 Houston, Texas, 77084 (281) 829-2225 Date: 4/18/2005 Report #200400299 I I Client: Well: Installation: BP Z210PB1 Nabors 7ES Field: Sand: Job #: Prudhoe Bay 200400299 ., I Table of Contents PVT Analysis on Sample#: .1.01;. CSB.14009~QA; OB.d. Sand; MD ;:;7493ft; TVD. ;:;:.4914 ft; TVDSS:;:A832.ft.. . Constant Composition Expansion. at .Tres. .. . ReselVoir Oil ViscositJ¡.at. Tres. . ReselVoir Oil Viscosity.at.6D~F.... ReselVoir Oil Viscosity.at. 7S°F. . . . ReselVoir Oil Viscosity.at 15D.~F . . ReselVoir Oil Viscosity.at.2DO°F . . PVT Analysis on Sample#: .1.06; CSB.14001~QA; OA Sand; MD.:;: 7.139. ft; WD:;: 4711 ft; IVDSS:;: "4629.ft.. Constant Composition Expansion. at .Tres. . . ReselVoir Oil Viscosity.at Tres. . ReselVoir Oil Viscosity.at6D.°F. . . ReselVoir Oil Viscosity.at.7S~F.... . . ReselVoir Oil Viscosity.at.I50.~F . . ReselVoir Oil Viscosity.at.2DO°F . . List of Figures List ofT abIes I EXECUTIVE SUMMARy..... Objective Introduction Scope of Work Results PVT Study Data auality.Cb.eck.Summary.. . Sequence of Events. Chain of Sample Custody. . . I I I RESULTS AND DlSCUSSlONS.... Fluids Preparation. and. Analysis ... ReselVoir Fluid Analysis. . . I I I I .. ...... ....... . .. ............. . . ...".......... . .. .. ........ .... ........ 3 4 5 5 5 5 5 6 7 7 8 8 8 30 30 32 34 36 38 40 43 43 45 47 49 51 53 PVT Analysis on Sample#: .1.09; CSB.14006~QA; DB.a~Lower Sand; MD. ;:;7263 ft; JVD. .::;:.11783. ft WDSS:;: ".47.01 It... Constant Composition Expansion. at .Tres . . . . ReselVoir Oil Viscosity.at. Tres. . . PVT Analysis on Sample#: .u0;.CSB.14004~QA; 08.&. Sand;. MD. ;:;7405ft; TVD. d864. ft; WOSS:;: "47.82.ft.. Constant Composition Expallsioo. at .Tres. . . . . ReselVoir Oil Viscosity.at Tres. . . WCP Oilphase-DBR .. ........ ......"".. 56 56 58 61 61 63 Job #: 200400299 I I Client: Well: Installation: BP Z21OPB1 Nabors 7ES Field: Sand: Job #: Prudhoe Bay ., 200400299 I Appendix A: Nomenclature and Definitions. . Appendix B: Mo.lecular Weights and. Densities. Used.... Appendix C: EOUIP.MENL. . Fluid Preparation and.Validation.. . Fluid Volumetric (PVTJ .and. Viscosity Equipment.. . Appendix D: PROC.EDURE... Fluids Preparation.aod Validation... Constant Composition. Expansion. Procedure. . ............ . Differential Vaporization. Procedure. ...... ...... ...... .... . ........ Multi-StageSeparatiaoTesL. .. .... .. ...... .......... .. ...... Liquid Phase Viscosity and Density Measurements.During DV Step.... Stock- Tank Oil (sro) ViscosiLy.aod DensiLy.Measurements.... Asphaltene, Wax and Sulfur.CaotentMeasurements... SAR(PJA Analysis .. High- Temperature High. Pressure. Filtration. Test.. . ...,.......... 65 66 67 67 67 70 70 70 70 70 71 71 71 72 72 I .. ". ..."". I I I I I I I I I I I I I I I WCP Oilphase-DBR 2 Job #: 200400299 I I Client: Well: Installation: BP Z210PB1 Nabors 7ES Field: Sand: Job #: Prudhoe Bay ., 200400299 I List of Figures I Figure 1: Stock Tank.OilCbromatogram.(Sample.1.01)... . Figure 2: k-Plot for.Eq.uilibrium .Check .(Sample.1.01). Figure 3: Stock Tank .Oil.Cbromatogram.(Sample1.02).. Figure 4: k-Plot for.Equilibrium .Check .(Sample.1.02)... Figure 5: Stock Tank .Oil.Cbromatogram.(Sample1.06).. . Figure 6: k-Plot for .EquiJibrium Check .(Sample.1.06)... . Figure 7: Stock Tank 0i1.Cbromatogram.(Sample1.07).. Figure 8: k-Plot for.Equilibrium .Check .(Sample.1.07I.. Figure 9: Stock Tank 0i1.Cbr.omatogram.(Sample.1.09).. Figure 10: k-Plot for Equilibrium.Check.(Sample.1.09).. Figure 11: Stock Tank Oil Chromatogram .(Sample.1.10).. Figure 12: k-Plot for Equilibrium. Check.(Sample.1.10)... Figure 13: Constant.Composition .Expansion .a199.oF c. Relative.Volume.. Figure 14: ReservoirFJuidViscosity.99°I (Sample. 1.01). Figure 15: ReservoirFJuid.Viscosity.60~F (Sample. 1.01).. . Figure 16: Reservoir .FJuid .Vis.cosity. 75°F (Sample. 1.0t).. Figure 17: ReservoirFJuid Viscosity. 150°f .(Sample1.01). . Figure 18: Reservoir.FJuidViscosity.200°F.(Sample.1.01). . Figure 19: Constant .Composition .Expansion .a196.oF. c. Relative. Volume... Figure 20: Reservoir.FJuid.Vis.cosity.96°.F(Sample. 1.06).. Figure 21: ReservoirFJuid.Vis.cosity.60°.F (Sample. 1.06).. Figure 22: Reservoir.FJuidViscosity 75°.F (Sample. 1.06).. Figure 23: Reservoir.FJuidViscosity 150°F.(Sample1.06). . Figure 24: Reservoir.FluidViscosity.200of .(Sample1.06). Figure 25: Constant.Composition .Expansion .a197°F .-. Relative Volume... Figure 26: ReservoirFJuidViscosity97°I (Sample. 1.09).. Figure 27: Constant .Composition .Expansion .a198°F c. Relative Volume. . Figure 28: Reservoir.FJuid.Viscosity98°I.... ........ ...... ... ....".".. 13 13 16 16 19 19 22 22 25 25 28 28 31 33 35 37 39 41 44 46 48 50 52 54 57 59 62 64 I I ....... ....... .""................... I ...."........ I I I I I I I I I I I I WCP Oilphase-DBR 3 Job #: 200400299 I I Client Well: Installation: 200400299 BP Z210PB1 Nabors 7ES Field: Sand: Job #: Prudhoe Bay I List of Tables .., Table 1: Well and.Sample.ldeotifi.ca.tioß.. ........................................ ........................................ ................. Table 2: Sampling and .Transfer Summary.. . ... ... .. ... ... . ... ..... ... ... . ... .'. .. ... . .. . ... ... .. .'. . ... ... ..... ... . ... .... ................. Table 3: Reservoir .fluid Pro.pe.rties. . ,. . . , . . . . . . . . . . .. . .. .......................,.................,.........,...,........... ................. Table 4: Stock-Tank. Oil. Properties. . .. . . . . .. . . . . . . . .. . . . . .. . . . . . . . .. . . . . . . . . . . . . . .. . . . . .. .................................................... Table 5: C30+ Compositioo..GOß..oAPI. by Zero"Flash.(Sample.1.01).... . Table 6: Calculated. Fluid. Properties.. . Table 7: C30+ Compositioß.GOß.oAPI.bvZero"Flash.(Sample1.02). Table 8: Calculated. Fluid. Properties.. . Table 9: C30+ Compositiou..GOß.. °API. bV Zero"Flash.(Sample.1.06)..... Table 10: Calculated Fluid .P.roperties.. Table 11: C30+ Composition. .GOR. .oAPI..by.Zero"Flash .(Sample. .1.07)... Table 12: Calculated Fluid .Properties.. Table 13: C30+ Composition. .GOR. .oAPI..by.Zero"Flash .(Sample. .1.09)... Table 14: Calculated Fluid .Properties.. Table 15: C30+ Composition. GOR. .oAPI..by.Zero"Flash(Sample. .1.10)... Table 16: Calculated Fluid Properties .. Table 17: SummaryofRes.ults.ofSampJe1.0L . Table 18: Constant .Composition .Expansion .at 99.~F (Samp.l.e.1.01).... Table 19: Reservoir.FJ.uid .Viscosity.99°.F. (Sample. tOn ... Table 20: Reservoír.FJuidViscosity.60~.F. (Sample.t01J.. Table 21: Reservoir.FIuid.ViscosityJ5°.F.{Sample.t01J... Table 22: Reservoir .Fluid Viscosity.1.50°F{Sample1.01l. Table 23: Reservoir.FIuid.Viscosity.200°F{Sample1.01) Table 24: Summary. of.Res.ults .of SampJe.1.06..... Table 25: Constant .Composition .Expansion .at 96.oF (Sample. 1.06) . . Table 26: Reservoir.FIuidViscosity.96°F. (Sample.1.06J.. Table 27: Reservoir.FluidVíscosity60°.F. (Sample.1.06J.. Table 28: Reservoir.FI.uidViscosity.75°.F.(Sample.1.06.).... Table 29: Reservoir.FJ.uidViscosity.150°F .(Sample .1.06). Table 30: Reservoir.FJuidViscosity.200~F .(Sample1.06). Table 31: Summary of Results .of Sample. to9.. . Table 32: Constant.Composition .Expansion .at 97°F (Sample. t09)... . ............... Table 33: Reservoir.FJuid.Viscosity.97°.F. (Sample.t09.).... Table 34: Summary ofRes.ults.of SampJe. 1...10 .... Table 35: Constant .Composition .Expansion .at 98.oF (Sample 1.10).. Table 36: Reservoir.FJuidViscosity98°.F.... I I ..... ..."........ . I . ". .... ......... I I I . .. "''''''''....,.."." . "'''''''''' . I ... .. ....... I .... ......."...... I I . ................, .... .. ..... .............. I I WCP Oilphase-DBR 4 9 9 10 10 11 12 14 15 17 18 20 21 23 24 26 27 29 30 32 34 36 38 40 42 43 45 48 49 51 53 55 56 58 60 61 63 Job #: 200400299 I I I I I I I I I I I Client: Well: Installation: BP Z210PB1 Nabors 7ES Field: Sand: Job #: Prudhoe Bay Scblumberger 200400299 EXECUTIVE SUMMARY Objective To establish the quality of bottomhole hole fluid samples collected from the subject well by a representative of Oilphase-DBR. The bottom hole samples were collected using Oilphase-DBR's Modular Formation Dynamics Tester (MDT). Introduction At the request of BP, Oil phase has conducted a fluid analysis study on the surface separator samples from the separator and the bottomhole fluid samples collected by Modular Formation Dynamics Tester (MDT) of Well Z210PB1 drilled in the field Prudhoe Bay. Scope of Work . Homogenize bottomhole samples at Tres and 8000 psi with continuous rocking for five days. · Conduct preliminary evaluation on bottomhole hydrocarbon samples that include single-stage flash Gas- Oil Ratio (GOR), reservoir fluid composition, stock-tank oil (STO) and monophasic fluid properties. · Select representative samples for the PVT study. · Conduct a Constant Composition Expansion (CCE) test at the reservoir temperature. · Conduct viscosity measurements of the oil at the required temperatures. · Conduct viscosity measurements of the oil at the reservoir temperature. Results The following bullets summarizes the fluid analyses conducted on the bottomhole samples: · Six bottomhole samples were used for validation purposes. They were homogenized at the reservoir conditions for five days. · The zero flash GOR was determined to be from 194 - 259 SCFjSTB, and the STO density to be from 0.920 - 0.961 gjcc. · All samples are considered valid for the full PVT study. Sample 1.01, 1,06, 1.09 and 1.10 were chosen for the further PVT testing. WCP Oilphase-DBR 5 Job #: 200400299 I I Client: Well: Installation: BP Z210PB1 Nabors 7ES Field: Sand: Job#: Prudhoe Bay Schlumbepgep 200400299 I Ouality Assurance Process I Oilphase-DBR Schlumberger is committed to providing unsurpassed services in bottom hole reservoir fluid sampling and fluid property analyses while maintaining high standards of safety and quality. Our objective is to deliver the most accurate and reliable sampling processes and fluid property measurements available in the industry. This objective requires persistent innovation and ongoing development of state-of-the-art technologies and equipment. I A rigorous quality assurance program, continuous employee training and enforcement of strict safety standards maintain our compliance with Quality, Health, Safety and Environment IQHSE) requirements. Proactive integration of QHSE objectives and management goals at every level supports the communication and implementation of QHSE policies and standards. I Schlumberger requires that qualified engineering technologists perform all laboratory measurements according to specified analytical procedures designed for obtaining accurate and reliable data. Rigorous quality assurance programs and instrument calibration protocols are in place to ensure and maintain the validity of the procedures. Details of these programs are available upon request. The lab-generated data undergoes the following five levels of quality checks to establish the integrity of the reported results. I a) Establish quality of measurement during data generation. bl Establish quality of processed data as per checklist during data processing by Data Quality Engineer. c) Data Quality Supervisor confirms the overall quality of the processed data and ensures cross correlative consistency d) The responsible Project Engineer confirms consistency of reported data e) Engineering Project Manager review the results/report for overall consistency I I Hence the completion of each project requires that a qualified and experienced team of engineers perform a variety of independent review of all technical data to confirm the consistency and accuracy of the report as per pre-established Quality checklists designed for each operation and based on the level of complexity. All property measurements and calculation procedures are maintained in company archives for a period of 1 year. This information is available for review by clients upon request. The file and laboratory records information are listed below to provide access reference to all records related to this project. For any questions, please do not hesitate to contact the undersigned Project Engineer. I File No,: 200400299 Laboratory Records: 200400299 I Data Quality Data Reporting Suyu Ye Meisong Yan I Data Quality Engineer Project Engineer I Overall Report Quality Dennis D'Cruz I Dennis D'cruz Engineering Project Manager I I I I I WCP Oi/phase-DBR 6 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: Well: Installation: BP Z210PB1 Nabors 7ES Field: Sand: Job#: Prudhoe Bay Schlumbepgep 200400299 Sequence of Events 11/05/04 11/16/04 12/01/04 12/03/04 12/27/04 12/30/04 01/07/05 02/05/05 02/10/05 02/11/05 Downhole amples arrived and informed client. Work agreement approved. Project work scope discussed. Prelim PVT tests request for all six samples issued. Sample PVT prelim testing finished. Double OC-ed sample 1.01 and 1.10 prelim results. Prelim results sent and Invoice generated. Invoice#: 9091318137. PVT tests request for sample 1.01, 1.06, 1.09 and 1.10 issued. Sample 1.06, 1.09 and 1.10 results sent via e-mail. Sample 1.01 results sent via e-mail. Invoice generated for the PVT study. Invoice#: 9091342891. Chain of Sample Custody The samples collected from the well Z21OPB1 from BP Alaska were sent to Oilphase-DBR in Houston, Texas. The samples were used to preliminary measurements and subsequent PVT study. The measurement details are in the following text. Samples remaining after measurements are stored in Oilphase-DBR storage unless otherwise instructed. WCP Oilphase-DBR 7 Job #: 200400299 I I Client: Well: Installation: BP WOPS1 Nabors 7ES Field: Sand: Job #: Prudhoe Bay ScblllDberger 200400299 RESUL 1S AND DISCUSSIONS I Fluids Preparation and Analysis Six bottomhole samples collected by MDT were transferred to Oilphase-DBR. The well and formation data with their respective reservoir/separator conditions for the samples are summarized in Table 1. The quality check for the bottom hole samples were conducted and the results are summarized in Table 2. After 5-day homogenization, sample validation test was conducted to evaluate the validity of the samples. Based on the preliminary results, representative samples can selected for PVT analysis. The reservoir fluid and stock-tank oil properties for all the samples are presented in Table 3 and Table 4. I I Reservoir Fluid Analysis The resulting gas and liquid from single-stage flash test were analyzed using gas chromatography to determine their compositions. These compositions were recombined mathematically according to single-stage flash Gas-Oil Ratio (GOR) to calculate the reservoir fluid composition. The reservoir fluid analyses are summarized in Table 5, 7, 9, 11, 13 and 15. Other properties such as the plus fraction properties and heat content for the flash gas were calculated from the compositions and are listed in Table 6, 8, 10. 12, 14 and 16. All samples are valid for the full PVT study. I I I I I I I I WCP Oilphase-DBR 8 Job #: 200400299 I Client: BP Well: Z210PB1 Insta lIation: Nabors 7ES Client: BP Job# 200400299 Field: Prudhoe Bay Well: Z210PB1 Sample ID Cylinder # Field: Sand: Job #: Prudhoe Bay SclllUD1b8t'glP I 200400299 I Table 1: Well and Sample Identification I Sand Name Sampling Date Opening Pres. in the field (psia¡OFI Pressure (psia) Reservoir Conditions Temperature MD TVD (OFI (ft) (ftl TVDSS (ft) I 1.01 CSB 14009-QA OBd 10/21/04 3,515/71 2,171 99 7493 4914 1.02 CSB 14005-QA OBd 10/21/04 3,515/71 2,171 94 7493 4914 1.06 CSB 14007-QA OA 10/21/04 3,015{l2 2,100 96 7139 4711 1.07 CSB 1400B-QA OA 10/21/04 3,015(72 2,115 90 7139 4711 1.09 CSB 14006-QA OBa_Lower 10/21/04 4,015{l2 2,102 97 7263 4783 1.10 CSB 14004-QA OBe 10/21/04 3,515{l2 2,137 98 7405 4864 -4832 -4832 -4629 -4629 -4701 -4782 I I I Opening Transfer Opening Initial Final Sample ID Chamber # Sand Name conditions Cylinder conditions FS&W BS&W Sample Sample in the field ID in the lab Volume Volume (psia¡OF) Ipsia¡OFI (eel (v/v%) leel leel 1.01 MRSC 242 OBd 3,515(71 CSB 14009-QA 1515/72 1 Trace 600 blowdown 1.02 MRSC 242 OBd 3,515(71 CSB 14005-QA 1515{l2 1.0 600 560 1.06 MRSC 292 OA 3,015{l2 CSB 14007-QA 1515{l2 5 1.0 600 blowdown 1.07 MRSC 292 OA 3,015(72 CS B 14008-QA 1515{l2 10 1.5 600 560 1.09 MPSR 1397 OBa_Lower 4,015(72 CS B 14006-QA 1515/72 1.0 425 blowdown 1.10 MPSR 1398 OBe 3,515(72 CSB 14004-QA 1215{l2 1.0 420 blowdown Table 2: Sampling and Transfer Summary I I I I I I I I I I I WCP Oilphase-DBR 9 Job #: 200400299 I I Client: BP Field: Prudhoe Bay SeII_barlllp Well: Z21 OPBl Sand: Installation: Nabors 7ES Job #: 200400299 Table 3: Reservoir Fluid Properties Zero Flash Saturation Molar Mass of Visc osity of Sample ID Cylinder # Sand Name MD TVDSS GOR* 80** Pressure monophasic Res. Fluid atTres fluid at Pres, Tres (It I (It) (scf/stb) (psia) (ePi 1.01 CSB 14009-QA OBd 7,493 -4832 259 1.1 06 1951 192 14.4 102 CSB 14005-QA OBd 7,493 -4832 258 188 106 CSB 14007 -QA OA 7,139 -4629 208 1.068 1693 238 105.0 1.07 CSB 14008-QA OA 7,139 -4629 208 237 109 CSB 14006-QA OBa_Lower 7,263 -4701 194 1077 1680 242 98.7 1.10 CSB 14004-QA OBe 7,405 -4782 240 1.120 1861 189 9.9 I I I I . Flashed gas volume (sef) per barrel of stock tank liquid @ 60°F .. Volume of live oil at it's bubble point pressure per flashed stock tank liquid volume @ 60°F I Table 4: Stock-Tank Oil Properties STO Properties Sample ID Cylinder # Sand Name MD TVDSS Molar Mass Density API (It) (It I (g/ee) 1.01 CSB 14009-QA OBd 7493 -4832 300.0 0.931 20.6 1.02 CSB 14005-QA OBd 7493 -4832 289.7 0.931 20.5 1.06 CSB 14007-QA OA 7139 -4629 371.0 0.961 15.8 1.07 CSB 14008-QA OA 7139 ·4629 3679 0.960 15.9 109 CSB 14006-QA OBa_Lower 7263 -4701 366.8 0.960 16.0 1.10 CSB 14004-QA OBe 7405 -4782 282.8 0.920 22.4 I I I I I I I I I I I . WCP Oilphase-DBR 10 Job #: 200400299 I I Client: Well: BP Z210PBl Field: Sand: Prudhoe Bay Obd lebluMberglP I Table 5: C30+ Composition, GOR, °API. by Zero-Flash (Sample 1.01) Sample#: 1.01; CSB 14009-QA; OBd Sand; MD = 7493 ft; TVD = 4914 ft; TVDSS = -4832 ft I Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole WT% MOLE % WT% MOLE % WT% MOLE % Carbon Dioxide 4401 8.76 3.77 0.00 0.00 0.33 145 Hydrogen Sulfid 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 2801 0.56 0.38 0.00 0.00 0.02 0.15 Methane 16.04 76.58 90.36 0.00 0.00 2.92 34.85 Ethane 3007 4.89 3.08 0.00 0.00 0.19 1.19 Propane 44.10 0.65 0.28 0.00 0.02 0.03 0.12 I - Butane 5812 0.73 0.24 0.01 0.03 0.03 0.11 N - Butane 5812 1.15 0.37 0.02 0.08 0.06 0.19 I - Pentane 72.15 1.07 0.28 0.05 0.19 0.09 0.23 N - Penta ne 72.15 1.17 0.31 0.07 0.30 0.11 0.30 C6 8400 1.60 0.36 0.21 0.76 0.27 0.60 M-C-Pentane 84.16 0.61 0.14 0.26 0.92 0.27 0.62 Benzene 78.11 0.02 0.01 0.00 0.02 0.01 0.01 Cyclohexane 84.16 040 0.09 0.31 1.11 0.31 0.72 C7 96.00 0.54 0.11 0.55 1.73 0.55 1.10 M-C-Hexane 9819 0.31 0.06 0.50 1.54 0.50 0.97 Toluene 92.14 0.51 0.11 007 0.23 0.09 0.18 C8 107.00 0.27 0.05 0.98 2.74 0.95 1.70 E-Benzene 106.17 0.01 0.00 0.09 0.27 0.09 0.16 M/P-Xylene 106.17 0.02 0.00 0.15 043 0.15 0.26 O-Xylene 106.17 0.00 0.00 0.10 0.29 0.10 0.18 C9 121.00 0.12 0.02 128 3.18 124 1.96 Cl0 13400 0.02 0.00 202 4.51 1.94 2.77 Cll 147.00 0.00 0.00 2.14 4.38 2.06 2.69 C12 161.00 0.00 0.00 2.69 5.01 2.59 3.08 C13 175.00 0.00 0.00 3.01 5.17 2.90 3.17 C14 190.00 0.00 0.00 3.35 5.30 3.23 3.25 C15 20600 0.00 0.00 3.58 5.21 344 3.20 C16 222.00 3.42 4.62 3.29 2.84 C17 23700 2.99 3.79 2.88 2.33 C18 251.00 3.27 3.90 3.14 240 C19 26300 3.16 361 304 2.22 C20 275.00 2.73 2.97 2.62 1.83 C21 291.00 2.55 2.62 245 1.61 C22 300.00 2.63 2.63 2.53 1.62 C23 31200 202 1.94 1.94 1.19 C24 324.00 2.08 1.93 2.00 118 C25 337.00 2.33 2.07 2.24 1.27 C26 349 00 1.71 147 1.64 0.90 C27 360.00 1.88 1.56 1.80 0.96 C28 37200 1.83 148 1.76 0.91 C29 382.00 1.99 1.57 1.92 0.96 C30 394.00 1.83 140 1.76 0.86 C31 404.00 1.67 1.24 1.61 0.76 C32 41500 1.45 1.05 1.39 0.64 C33 42600 1.30 0.92 1.25 0.56 C34 437.00 1.58 1.09 1.52 0.67 C35 445.00 1.14 0.77 1.10 047 C36+ 75000 34.97 13.99 3364 8.59 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 18.93 299.95 191.56 MOLE RATIO 0.3857 0.6143 I I I I I I I I I I I I I I I WCP Oilphase-DBR 11 Job #: 200400299 I I Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay Dbd SchlUmbøPl8r I Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass % Mole % Mass % Mole% Mass % Mole% C7+ 2.83 0.58 99.65 98.62 95.96 60.81 C12+ 0.00 000 9118 77.29 8770 47.48 C20+ 6570 40.69 63.20 25.00 C36+ - 34.97 13.99 33.64 8.59 Molar Mass C7+ 92.66 30306 302.29 C12+ - 353.83 353.83 C20+ 484.29 484.29 C36+ 750.00 750.00 Density C7+ 0.9320 C12+ 0.9500 o 9500 C20+ - 10025 1.0025 C36+ 1.1231 1.1231 Fluid at 60°F 0.9305 Gas Gravity (Air = 1) I 0654 I Dry Gross Heat Content IBTU/scf) 1,064 I Wet Gross Heat Content (BTU/sc~ 1,046 I OBM Contamination Level (wt"lo) I - I STO Basis I ILive Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+ Properties MW I 296.07 I 29995 I I 750.00 I Density Ig/cm311 0931 I I I 1.123 I Single Stage Flash Data Original STO De-Contami nated GOR Iscf/stb) 259 I STO Density (g/cm3) 0.9305 STO API Gravity 20.6 OBM Density (g/cm3) @60°F Table 6: Calculated Fluid Properties Sample#: 1.01; CSB 14009-QA; OBd Sand; MD = 7493 ft; TVD = 4914 ft; TVDSS = -4832 ft I I I I I I I I I I I I I I I I WCP Oilphase-DBR 12 Job #: 200400299 Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay Obd I Figure 1: Stock Tank Oil Chromatogram (Sample 1.111) Sample# 1.01; CSB 14009-QA; OBd Sand; MD = 7493 ft; TVD 4914 ft; TVDSS = -4832 ft I I 700 500 500 400 IJJ - Ü 300 200 100 10 20 30 40 50 min I I I I I Figure 2: k-l'lot for Equilibrium Check (Sample 1.(n) Sample# 1.01; CSB 14009-QA; OBd Sand; MD = 7493 ft; TVD = 4914 ft; TVDSS -4832 ft _._._.~--- I 2.50 2.00 ISO . 100 ë:. .. C6 .., 050 e; '" ..... 000 .. ~ C8 0.50 100 -1.50 400 -JOO 200 ·100 000 ., C3 I .I1C4 I I 100 200 100 I -~~~-_._----~.~----- I I I I WCP Oilphase-DBR 13 Job #: 200400299 I I Client: Well: BP Z210PBl Field: Sand: Prud hoe Bay Obd SchlulßllePDe, I Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT% MOLE % WT% MOLE % WT% MOLE % Carbon Dioxide 44.01 8.84 3.77 0.00 0.00 0.33 142 Hydrogen Sulfíd 34.08 000 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 0.13 0.09 0.00 0.00 0.00 0.03 Methane 16.04 77.64 90.85 0.00 0.00 2.92 34.16 Ethane 30.07 495 3.09 0.00 0.00 0.19 1.16 Propa ne 44.10 0.61 0.26 0.00 0.03 0.03 0.12 I - Butane 58.12 0.66 0.21 0.01 0.05 0.03 0.11 N - Butane 58.12 1.07 0.35 0.03 0.13 0.07 0.21 I - Pentane 72.15 096 0.25 007 0.27 0.10 0.26 N - Pentane 72.15 1.09 0.28 0.11 042 0.14 0.37 C6 84.00 144 0.32 041 143 045 101 M-C-Pentane 84.16 066 0.15 0.34 1.17 0.35 0.79 Benzene 78.11 0.01 0.00 0.01 0.03 0.01 0.02 Cyclohexane 84.16 046 0.10 041 140 041 0.91 C7 9600 0.60 0.12 0.74 2.24 0.74 144 M-C-Hexane 98.19 039 007 0.66 1.95 0.65 1.24 Toluene 92.14 0.06 001 0.01 0.02 0.01 0.02 C8 107.00 028 0.05 138 3.74 134 2.35 E-Benzene 106.17 003 0.01 0.18 0.50 0.18 0.32 M/P-Xylene 106.17 0.02 0.00 0.24 0.64 0.23 040 O-Xylene 106.17 000 0.00 0.11 0.30 0.11 0.19 C9 121.00 009 0.01 1.51 3.62 146 2.26 Cl0 134.00 0.02 0.00 2.40 5.19 2.31 3.24 Cl1 147.00 0.01 0.00 2.43 4.80 2.34 2.99 C12 161.00 000 0.00 2.91 5.24 2.81 3.27 C13 175.00 0.00 0.00 3.21 5.31 3.09 3.32 C14 190.00 0.00 0.00 3.41 5.19 3.28 3.24 C15 206.00 0.00 0.00 3.53 4.97 340 3.10 C16 222.00 3.45 4.51 3.32 2.81 C17 237.00 3.25 3.97 3.13 248 C18 251.00 2.97 3.43 2.86 2.14 C19 263.00 3.03 3.33 2.91 2.08 C20 275.00 2.79 2.94 2.69 1.84 C21 291.00 244 2.43 2.35 1.51 C22 300.00 2.30 2.22 2.21 138 C23 312.00 2.10 1.95 2.02 1.22 C24 324.00 2.04 1.82 1.96 1.14 C25 337.00 1.66 1.43 1.60 0.89 C26 349.00 1.71 1.42 1.65 0.89 C27 360.00 1.50 1.21 145 0.75 C28 372.00 1.40 1.09 135 0.68 C29 382.00 1.72 130 1.65 0.81 C30 394.00 0.98 0.72 0.95 0.45 C31 404.00 0.78 0.56 0.75 0.35 C32 415.00 0.98 0.69 0.95 043 C33 426.00 0.88 0.60 0.84 0.37 C34 437.00 0.66 044 0.64 0.27 C35 445.00 0.60 0.39 0.57 0.24 C36+ 750.00 38.65 14.93 37.20 9.31 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 18.77 289.67 187.80 MOLE RATIO 0.3760 0.6240 Table 7: C30+ Composition, GOR, °API, by Zero-Flash (Sample 1.02) Sample#: 1.02; CSB 14005-QA; OBd Sand; MO = 7493 ft; TVO = 4914 ft; TVOSS = -4832 ft I I I I I I I I I I I I I I I I WCP Oilphase-DBR 14 Job #: 200400299 I I Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay Obd SchlumblPII. I Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass % Mole % Mass % Mole% Mass % Mole% C7+ 2.62 0.53 99.37 9767 95.7 4 61.14 C12+ 0.00 0.00 88.96 12.09 85.61 44.98 C20+ - 63.19 36.13 60.82 22.54 C36+ 38.65 14.93 37.20 9.31 Molar Mass C7+ 92.69 294.71 294.05 C12+ 357.45 357.45 C20+ - 506.65 506.65 C36+ 750.00 750.00 Density C7+ 0.9335 C12+ 09568 0.9568 C20+ 1.0166 1.0166 C36+ 1.1179 1.1179 Fluid at 60°F 0.9309 Gas Gravity (Ai r = 11 0648 Dry Gross Heat Content (BTU/scf) 1.061 Wet Gross Heat Content (BTU/sc~ 1.043 OBM Contamination level (wt%1 ISTO Basis I - ILive Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+ Properties MW I 284.39 I 289.67 I I 750.00 I Density (g/cm3) I 0.931 1.118 Single Stage Flash Data Original STO De-Contaminated GOR (scf/stbl 258 I STO Density (g/cm3) 0.9309 I STO API Gravity 20.5 OBM Density (g/cm3) @60°F I I Table 8: Calculated Fluid Properties Sample#: 1.02; CSB 14005-QA; OBd Sand; MD = 7493 ft; TVD = 4914 ft; TVDSS = -4832 ft I I I I I I I I I I I I I I I I WCP Oilphase-DBR 15 Job #: 200400299 I I Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay Obd I Figure 3: Stock Tank Oil Chromatogram (Sample 1.02) Sample#: 1,02; CSB 14005-QA; OBd Sand; MD = 7493 ft; TVD = 4914 ft; TVDSS -4832 ft NQrm J JOB 200400299 BP 1.02 CSB 14005 RF FLASH CYLINDER I 350 I 300 250 I 200 I 150 to U 6 (j :~ ü ~ 50 I 100 I o o W ffi æ æ æ æ Figure 4: k-Plot for Equilibrium Check (Sample 1.02) Sample# 102; CSB 14005-QA; OBd Sand; MD 7493 ft; TVD 4914 ft; TVDSS = -4832 ft rrd I ~^'-~.~~..~..._..~"-~~-~- --,---~~._._~~._-~._._.._.__.~-- I 2.50 2.00 . ìC4 I 1.50 100 ... .>II. 0.50 <:;; Q ..J 000 050 100 150 4.00 300 <I> C9 I I 200 100 000 100 200 300 I F _._____~~'_M_~.. I I I I WCP Oilphase-DBR 16 Job II: 200400299 I I Client: Well: BP Z210PBl Field: Sand: Prudhoe Bay OA Schlum_epgll' I Table 9: C30+ Composition. GOR. °API. bV Zero-Flash (Sample 1.06) Sample#: 1.06; CSB 14007-QA; OA Sand; MD = 7139 ft; TVD = 4711 ft; TVDSS = -4629 ft I Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT% MOLE % WT% MOLE % WT% MOLE % Carbon Dioxide 4401 7.44 2.88 0.00 0.00 0.20 109 Hydrogen Sullid 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 0.22 0.13 0.00 0.00 0.01 0.05 Methane 16.04 90.7 4 96.42 0.00 0.00 2.45 36.33 Ethane 3007 0.64 0.36 0.00 0.00 0.02 0.14 Propane 44.10 0.04 0.02 0.00 0.00 0.00 0.01 I - Butane 58.12 0.08 0.02 0.00 0.00 0.00 0.01 N - Butane 58.12 0.03 0.01 0.00 0.00 0.00 0.01 I - Penta ne 72.15 0.04 0.01 0.00 0.01 0.00 0.01 N - Pentane 72.15 0.07 0.02 0.02 0.08 0.02 0.06 C6 84.00 0.10 0.02 0.04 0.17 0.04 0.11 M-C-Pentane 8416 0.02 0.00 0.00 0.02 0.00 0.01 Benzene 78.11 0.00 0.00 0.00 0.01 0.00 0.00 Cyclohexane 84.16 0.01 0.00 0.00 0.01 0.00 0.01 C7 9600 0.07 0.01 0.05 0.21 0.05 0.13 M-C-Hexane 98.19 0.03 0.00 0.01 0.03 0.01 0.02 Toluene 92.14 0.31 0.06 0.39 1.56 0.39 0.99 C8 107.00 0.07 0.01 0.09 0.30 0.09 0.19 E-Benzene 106.17 0.01 0.00 0.01 0.02 0.01 0.01 M/P-Xylene 106.17 0.00 0.00 0.00 0.01 0.00 0.01 O-Xylene 106.17 0.00 0.00 0.00 0.01 0.00 0.00 C9 121.00 0.06 0.01 0.19 0.59 0.19 0.37 Cl0 134.00 0.01 0.00 0.44 1.23 0.43 0.77 Cl1 147.00 0.00 0.00 0.88 2.23 0.86 1.39 C12 161.00 0.00 0.00 1.47 3.39 1.43 2.11 C13 175.00 000 0.00 1.95 4.13 1.89 2.57 C14 190.00 0.00 0.00 2.29 4.47 2.23 2.79 C15 20600 0.00 000 2.77 499 2.70 311 C16 222.00 3.06 5.11 2.97 3.18 C17 237.00 2.93 459 2.85 2.86 C18 251.00 3.36 4.97 3.27 3.09 C19 263.00 3.13 4.42 305 2.76 C20 27500 3.37 455 328 2.84 C21 291.00 2.85 3.63 2.77 2.26 C22 300.00 2.78 3.44 2.71 2.14 C23 312.00 2.62 311 2.55 1.94 C24 324.00 2.59 2.96 2.52 1.85 C25 337.00 2.20 2.42 2.14 1.51 C26 349.00 2.27 2.41 2.20 1.50 C27 360.00 206 2.13 201 1.33 C28 372.00 1.94 1.93 1.88 1.20 C29 382.00 2.40 2.33 2.33 1.45 C30 394.00 1.47 1.38 1.43 0.86 C31 404.00 1.13 104 1.10 0.65 C32 415.00 1.46 1.30 1.42 0.81 C33 426.00 1.29 1.12 1.26 0.70 C34 437.00 104 0.89 102 0.55 C35 445.00 0.97 0.81 0.94 0.50 C36+ 750.00 44.48 22.00 43.28 13.71 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 17.05 370.99 237.64 MOLE RATIO 0.3768 06232 I I I I I I I I I I I I I I I WCP Oilphase-DBR 17 Job #: 200400299 I I Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay OA Seblolllbl"" I Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass % Mole % Mass % Mole% Mass % Mole% C7+ 0.60 0.11 9994 99.74 97.26 62.20 C12+ 0.00 0.00 9787 93.52 95.22 58.28 C20+ - 76.91 57.46 74.83 35.81 C36+ - 44.48 22.00 43.28 13.71 Molar Mass C7+ 97.21 371.75 371.58 C12+ 38826 388.26 C20+ - 496.60 496.60 C36+ 750.00 750.00 Density C7+ 0.9609 C12+ 0.9651 0.9651 C2O+ - 1.0057 1.0057 C36+ 1.1097 1.1097 Fluid at 60°F 0.9606 Gas Gravity (Air = 1) I 0.589 I Dry Gross Heat Content (BTU/scfll 991 I Wet Gross Heat Content (BTU/sc~ 974 I OBM Contamination Level (wt''101 I ISTO Basis I ¡Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+ Properties MW I 366.43 I 370.99 I I 750.00 Density (g/cm3) I 0.961 I I I 1.110 I Single Stage Flash Data Original STO De-Contaminated GOR (scllstb) 208 STO Density (g/cm3) I 0.9606 STO API Gravity 15.8 - OBM Density (g/cm3) @60°F Table 10: Calculated Fluid Properties Sample#: 1.06; CSB 14007-QA; OA Sand; MD = 7139 ft; TVD = 4711 ft; TVDSS = -4629 ft I I I I I I I I I I I WCP Oilphase-DOR 18 Job #: 200400299 I I Client: Well: BP Z21 OPBl Field: Sand: Prudhoe Bay OA I figure 5: Stock Tank Oil Chromatogram (Sample 1.06) Sample#: 1.06; CSB 14007-QA; OA Sand; MD = 7139 ft; TVD 4711 ft; TVDSS = -4629 ft Norm, I 350 JOB 200400299 BP 1.06 CSB 14007 RF FLASH CYLINDER I 300 250 I 200 I 150 50 m w m ~ æ _ figure 6: k-Plot for Equilibrium Check (Sample 1.06) Sample# 106: CSB 14007 -QA; OA Sand; MD = 7139 ft; TVD = 4711 ft; TVDSS = -4629 ft mi I 100 I o o I _.~~~--~-"_..~.....~~-----~_.~,_.~_....._----~--~-_...~-~ I 100 2,50 200 150 Q: "'" 100 c;; .:¡ 050 000 .. C8 050 100 400 300 200 . iC4 I '" I '" C6 I 100 000 100 2,00 300 I f ~~-,..~._-~~~---~~----~ '~'-"'----~---~~'~~-~'--- I I I I WCP Oilpl1ase-DBR 19 Job #: 200400299 I I Client: Well: BP Z210PB1 Field: Sand: Prud hoe Bay OA Schlomltergll' I Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/molel WT% MOLE % WT% MOLE % WT% MOLE % Carbon ~ioxide 44.01 745 2.87 0.00 0.00 0.20 1.08 Hydrogen Sulfid 3408 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 0.15 0.09 0.00 0.00 0.00 0.03 Methane 16.04 91.24 96.56 0.00 0.00 2A5 36.13 Ethane 30.07 0.65 0.37 0.00 0.00 0.02 0.14 Propane 44.10 0.04 0.01 0.00 0.00 0.00 0.01 I - Butane 58.12 0.08 0.02 0.00 0.00 0.00 0.01 N - Butane 58.12 0.01 0.00 0.00 0.01 0.00 0.01 I - Penta ne 72.15 0.02 0.01 0.00 0.01 0.00 0.01 N - Pentane 72.15 0.04 0.01 0.03 0.15 0.03 0.10 C6 84.00 0.05 0.01 0.03 0.15 0.03 0.10 M-C-Pentane 84.16 0.01 0.00 0.00 0.01 0.00 0.01 Benzene 78.11 0.00 0.00 0.00 0.01 0.00 0.00 Cyclohexane 84.16 0.00 0.00 0.00 0.01 0.00 0.01 C7 96.00 003 001 om 0.27 0.07 0.17 M-C-Hexane 98.19 0.01 0.00 0.00 0.02 0.00 0.01 Toluene 92.14 0.11 002 0.19 0.74 0.18 OA7 C8 107.00 0.03 0.00 0.09 0.32 0.09 0.20 E-Benzene 106.17 0.01 0.00 0.01 0.02 0.01 0.02 M/P-Xylene 106.17 0.00 0.00 0.00 0.01 0.00 0.01 O-Xylene 106.17 0.00 0.00 0.00 0.01 0.00 0.00 C9 121.00 0.04 0.01 0.21 0.63 0.20 DAD Cl0 134.00 0.01 0.00 OA6 126 OA5 0.79 Cll 147.00 0.00 0.00 0.91 2.27 0.88 1A2 C12 161.00 0.00 0.00 1.51 3.46 1A7 2.16 C13 175.00 0.00 0.00 2.01 4.23 1.96 2.64 C14 190.00 0.00 0.00 2.36 4.58 2.30 2.87 C15 206.00 0.00 0.00 2.87 5.12 2.79 3.21 C16 222.00 317 5.25 3.08 3.28 C17 237.00 3.05 4.73 2.96 2.96 C18 251.00 3A7 5.09 3.38 3.18 C19 263.00 3.22 4.50 3.13 2.81 C20 275.00 3A7 4.64 3.37 2.90 C21 291.00 2.92 3.69 2.84 2.31 C22 300.00 2.86 3.50 2.78 2.19 C23 312.00 2.69 3.17 2.61 1.98 C24 324.00 2.66 3.02 2.59 1.89 C25 337.00 2.25 2A5 2.19 1.54 C26 349.00 2.31 2A4 2.25 1.52 C27 360.00 2.10 2.14 2.04 1.34 C28 372.00 2.00 1.98 1.95 1.24 C29 382.00 2A2 2.33 2.36 lA6 C30 394.00 1.51 1A1 1A6 0.88 C31 404.00 1.16 1.05 1.13 0.66 C32 415.00 1A9 1.32 1A5 0.82 C33 426.00 1.30 1.12 1.27 0.70 C34 437.00 1.10 0.93 1.07 0.58 C35 445.00 0.98 0.81 0.95 0.50 C36+ 750.00 43.13 21.16 41.97 13.24 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 16.98 367.87 236.58 MOLE RATIO 0.3742 0.6258 Table 11: C30+ Composition, GOR, °API,by Zero-Flash (Sample 1.07) Sample#: 1.07; CSB 14008-QA; OA Sand; MD = 7139 ft; TVD = 4711 ft; TVDSS = -4629 ft I I I I I I I I I I I I I I I I WCP Oilphase-DBR 20 Job #: 200400299 I I Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay OA lahluml8rglr I Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass % Mole % Mass % Mole% Mass % Mole% C7+ 0.26 0.04 9993 99.68 97.26 62.40 C12+ 000 0.00 97.99 94.10 9536 58.89 C20+ - 7633 57.16 74.28 35.77 C36+ - 43.13 21.16 41.97 13.24 Molar Mass C7+ 99.46 368.81 36874 C12+ 161.00 383. 07 383.07 C20+ - 491.29 491.29 C36+ 750.00 750.00 Density C7+ 0.9605 C12+ 0.9647 0.9647 C20+ - 10070 10070 C36+ 11189 1.1189 Fluid at 60°F 0.9602 Gas Gravity (Air = 1) 0.586 Dry Gross Heat Content (BTU/sc!) 988 Wet Gross Heat Content (BTU/sc~ 971 OBM Contamination level (wt%) STO Basis Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+ Properties MW I 364.28 367.87 750.00 Density (g/cm3) I 0960 1119 Single Stage Flash Data Original STO De-Contami nated GOR (scf/stb) 208 I STO Density (g/cm3) o 9602 STO API Gravity 15.9 OBM Density (g/cm3) @60°F I - I Table 12: Calculated Fluid Properties Sample#: 1.07; CSB 14008-QA; OA Sand; MD = 7139 ft; TVD = 4711 ft; TVDSS = -4629 ft I I I I I I I I I I I I I I I I WCP Oilphase-DBR 21 Job #: 200400299 - ------------ , II I , , II I i II I I I I I I I I I I I I I I I I Client: Well: Field: Sand: Prudhoe Bay OA BP 2210PB1 Figure 1: Stock Tank Oil Chromatogram (Sample 1.01) Sample#: 1.07; CSB 14008-QA; OA Sand; MD 7139 ft; TVD = 4711 ft; TVDSS = -4629 ft Norm. I I JOB 200400299 BP 1.07 CSB 14008 RF FLASH CYLINDER 350 300 250 200 150 100 50 o o mil 10 W æ z w æ Figure 8: k-Plot for Equilibrium Check (Sample 1.(1) Sample# 107; CSB 14008-QA; OA Sand; MD = 7139 ft; TVD = 4711 ft; TVDSS = -4629 ft ~---_._-_..,~~^-_.,~.- 300 2.50 2.00 1.50 Q:. .... 1.00 c; " ..... 0.50 000 0.50 ~ C9 100 2.50 200 1.50 1.00 0.50 000 ------~~~ ~_._-~~--~- WCP Oilpltase-DBR 22 ~ ~ C3 0.50 1.00 200 300 1.50 2.50 Job #: 2001100299 I I Client: Well: BP Z210PBl Field: Sand: Prudhoe Bay LOWER Oba leblllltel'll' I Table 13: C30+ Composition, GOR, °API, by Zero-Flash (Sample 1.09) Sample#: 1.09; CSB 14006-QA; DBa_Lower Sand; MD = 7263 ft; TVD = 4783 ft; TVDSS = -4701 ft I Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT% MOLE % WT% MOLE % WT% MOLE % Carbon Dioxide 44.01 941 3,69 0,00 0,00 0,24 1.32 Hydrogen Sulfid 34,08 0,00 000 0,00 0.00 0,00 0,00 Nitrogen 28.01 021 0,13 0,00 0,00 0,01 0,05 Methane 16.04 88,77 9549 0,00 0.00 2.27 34.21 Ethane 30.07 0.84 048 0,00 0,00 0,02 0,17 Propane 4410 0.15 0,06 0,00 0,00 0,00 0,02 I - Butane 5812 0.17 0,05 0,00 0.00 0,00 0,02 N - Butane 5812 0,07 0.02 0,00 0,02 0.00 0,02 I - ~entane 72.15 0,05 001 000 0.02 0,00 0,01 N - Pentane 72.15 0.08 002 0.01 0.06 0,01 0,05 C6 84.00 007 0.01 0.04 0.18 0.04 0,12 M-C-Pentane 84,16 0.01 0,00 0.01 0.02 0.01 0,02 Benzene 78,11 0,00 0.00 000 0,00 0.00 0,00 Cyclohexane 84,16 0,01 0.00 0.01 0,03 0.01 0.02 C7 96,00 0,04 001 0.07 0,26 0.07 0,17 M-C-Hexane 98,19 0,02 0.00 0.02 0,06 0.02 0,04 Toluene 92,14 0,03 0,01 045 1,80 044 1,16 C8 107,00 0,03 0,00 011 0.39 0,11 0,25 E-Benzene 10617 0,00 0,00 001 0,03 0,01 0,02 M/P-Xylene 106,17 0,00 0,00 000 0,01 0.00 0.01 O-Xylene 106,17 0,00 0,00 0,00 0,01 0,00 0.01 C9 121.00 0,02 0,00 017 0,52 0,17 0.33 Cl0 134,00 0,00 O,qO 0.38 1,04 0.37 0,67 Cl1 147,00 0,00 0,00 0.75 186 0.73 1.19 C12 161,00 0,00 0,00 1.35 308 1.32 1.98 C13 175,00 0,00 0,00 1,82 382 178 245 C14 190,00 0,00 0,00 2,18 4,21 2,13 2.70 C15 206,00 0,00 0,00 276 4,91 2,68 3.15 C16 222,00 3.03 501 2,96 322 C17 237,00 3.04 4.71 2,97 302 C18 251,00 3.55 5,19 346 3.33 C19 263.00 3.39 472 330 3.03 C20 275,00 3,54 4,72 3.45 3.03 C21 291,00 3.08 388 300 249 C22 300,00 2,97 3.63 2,89 2.33 C23 312,00 2,80 329 273 2,11 C24 324,00 2.77 314 270 201 C25 337. 00 2.34 2,54 2,28 1.63 C26 349,00 244 2,57 2.38 1,65 C27 360,00 2,17 2,22 2,12 142 C28 372,00 207 2,05 202 1.31 C29 382,00 2.51 2.41 244 1,55 C30 394,00 1.54 143 1,50 0,92 C31 404,00 1,21 1,10 118 0.70 C32 415,00 1,55 1.37 1,51 0,88 C33 426,00 1.39 1,20 1.35 077 C34 437,00 109 0,92 1,06 0,59 C35 445,00 102 0,84 0,99 054 C36+ 75000 42.35 20.71 41.26 1329 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 17,26 366 85 241,61 MOLE RATIO 0.3582 0,6418 I I I I I I I I I I I I I I I WCP Oilphase-DBR 23 Job #: 200400299 I I Client: Well: BP 2210PB1 Field: Sand: Prudhoe Bay LOWER Dba SchlUmbll'llBP I Table 14: Calculated Fluid Properties Sample#: 1,09; CSB 14006-QA; DBa_Lower Sand; MO = 7263 ft; TVO = 4783 ft; TVOSS = -4701 ft I Properties Flashed Gas Flashed liquid Monophasic Fluid Cn+ Composition Mass % Mole % Mass % Mole% Mass % Mole% C7+ 0.17 0,03 99,94 99,72 97.39 64,00 C12+ 0,00 0,00 97,96 93,67 95.45 60,11 C20+ 76,83 58,00 74,87 37,22 C36+ - 42.35 2071 41,26 13.29 Molar Mass C7+ 98,28 367.67 36762 C12+ 161.00 383.67 383.67 C20+ 485.93 485,93 C36+ 750,00 750,00 Density C7+ - 0.9599 C12+ 09638 0,9638 C20+ 1,0040 1.0040 C36+ 1,1195 1,1195 Fluid at 60°F 0,9596 Gas Gravity (Air = 1) 0,596 Dry Gross Heat Content (BTUlscfl 982 I [Wet Gross Heat Content (BTUlsc~ 965 OBM Contamination Level (wt"lo) I ISTO Basis I ILive Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+ Properties MW I 364,18 I 366,85 I I 75000 I Density (g/cm311 0,960 I I I 1.120 I Single Stage Flash Data Original STO De-Contaminated GOR (scllstbl 194 I STO Density (g/cm3) 0.9596 I STO API Gravity 16,0 OBM Density (g/cm3) @60°F I I I I I I I I I I I I WCP Oilphase-DBR 24 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: We!: BP Z210PBl Field: Sand: Prudhoe Bay LOWER Oba Figure 9: Stock Tank Oil Chromatogram (Sample 1.09) Sample#: 1.09; CSB 14006-QA; DBa_Lower Sand; MD 7263 ft; TVD 4783 ft; TVDSS = -4701 ft ijÜfffi. I JOB 200400299 BP 1.09 CSB 14006 RF FLASH CYLINDER 360 300 260 200 160 100 ill C ID ~ 50 o 010 16 20 26 30 36 figure 10: k-Plot for Equilibrium Check (Sample 1.09) Sample#: 1.09; CSB 14006-QA; DBa_Lower Sand; MD = 7263 ft; TVD = 4783 ft; TVDSS = -4701 ft mir .100 2.50 ~ iC4 200 150 '" nC4 =: 100 "'" 0;; <I; nC5 '" 050 ..¡ 000 </p C7 050 100 150 200 ·1.50 1.00 050 000 0.50 100 1.50 2.00 250 .100 F WCP Oilphase-DBR 25 Job #: 200400299 I I Client: Well: BP Z210PBl Field: Sand: Prudhoe Bay Obc Schlllberg8' I Table 15: C30+ Composition, GOR, °API, by Zero-Flash (Sample 1.10) Sample#: 1,10; CSB 14004-QA; OBc Sand; MD = 7405 ft; TVD = 4864 ft; TVDSS = -4782 ft I Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT% MOLE % WT% MOLE % WT% MOLE % Carbon Dioxide 44,01 7.76 3.48 0,00 0,00 0,29 1,24 Hydrogen Sulfid 34,08 0,00 0,00 0.00 0,00 0,00 0,00 Nitrogen 2801 0,51 0.36 0,00 0,00 0,02 013 Methane 1604 72.86 89,60 0,00 0,00 2,72 31.98 Ethane 30.07 2.85 1,87 0,00 0,00 0,11 0,67 Propa ne 4410 1.52 0,68 0.01 0,05 0.06 0,28 I - Butane 5812 1.76 0,60 0,02 0,11 0,09 028 N - Butane 5812 2,95 1,00 0,06 0.30 0,17 0,55 I - Pentane 72.15 2.30 0,63 0,14 0,55 0,22 0,58 N - Pentane 72.15 2.51 0,69 0.21 0,84 0.30 0.78 C6 8400 2.31 0,54 0.37 1,24 044 0,99 M-C-Pentane 84,16 0,52 0,12 0,24 0,80 0,25 0,56 Benzene 7811 0,00 0,00 0.00 0.01 0.00 0,01 Cyclohexane 84,16 0,28 0,06 0,26 0,86 0,26 0,58 C7 96,00 0.78 0,16 0,80 2.36 0,80 1,58 M-C-Hexane 98,19 0.33 007 0,59 1.70 0,58 1,12 Toluene 92,14 0,08 0,02 0,08 0,26 0,08 0,17 C8 107.00 0.38 0,07 1.44 3.81 1.40 2.47 E-Benzene 106,17 0,02 0,00 0,13 0.34 0,12 0.22 M/P-Xylene 106,17 0,03 0,01 0,23 0,61 0,22 0.40 O-Xylene 10617 0,01 0.00 0,13 0.33 0,12 0,21 C9 121,00 0,22 0,04 1,90 4.45 1,84 2.88 Cl0 134,00 0,03 0,00 2,69 568 2,59 3,65 Cll 147,00 0.00 0,00 2,63 5,06 2,53 3.25 C12 16100 0,00 0,00 3.07 5.39 2,95 3.46 C13 17500 0,00 0,00 3,26 5,27 3.14 3.39 C14 190,00 0,00 0,00 3.43 5,10 3.30 3.28 C15 206,00 0,00 0.00 3.53 4,85 3.40 3.12 C16 222,00 3.20 4,08 3.08 262 C17 237,00 2.79 3.33 2,68 2,14 C18 251,00 3.02 3.41 2,91 2,19 C19 263.00 2.91 3.13 2.80 201 C20 275.00 2.48 2.55 2.39 1,64 C21 291,00 2.32 2,25 2,23 1.45 C22 300,00 2.39 2,25 2.30 1.45 C23 312,00 2.04 1,85 1,96 1,19 C24 324,00 1,93 1,68 1.85 1,08 C25 337,00 1,86 1,56 1.79 101 C26 349,00 1.53 1.24 1.47 0,80 C27 360,00 1.75 1.37 1,68 0,88 C28 372,00 1,63 1,24 1,57 0,80 C29 382,00 1,81 1.34 1.74 0,86 C30 394,00 1.69 1.21 1,63 0.78 C31 404,00 1.50 105 144 0,68 C32 415,00 1.33 0,90 1.28 0,58 C33 426,00 1.41 094 1.36 0,60 C34 437,00 1.22 0.79 118 0,51 C35 445,00 1,09 069 1.05 0.45 C36+ 750,00 34,87 13.15 33.57 8.46 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 19.73 282.78 188.89 MOLE RATIO 0.3569 0,6431 I I I I I I I I I I I I I I I WCP Oilphase-DBR 26 Job #: 200400299 I I Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay Obc Sellalllargep I Properties Flashed Gas Flashed Liquid MonoDhasic Fluid Cn+ Composition Mass % Mole % Mass % Mole% Mass % Mole % C7+ 2.67 0.55 9918 96.90 95.59 6251 C12+ 0.00 0.00 88.06 70.62 84.78 4542 C20+ - 62.85 3608 60.51 23.20 C36+ 34.87 13.15 33. 57 846 Molar Mass C7+ 95.60 28944 288.83 C12+ - 352.59 352.59 C20+ - 492.61 492.61 C36+ - 750.00 75000 Density C7+ - 0.9230 C12+ 0.9462 0.9462 C20+ 0.9994 0.9994 C36+ 1.1045 1.1045 Fluid at 60°F 0.9196 Gas Gravity (Ai r ~ 11 0.681 Dry Gross Heat Content (BTU/scf) 1,116 Wet Gross Heat Content (BTU/sc~ 1,096 OBM Contamination Level Iwt"lo) STO Basis Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+ Properties MW I 281.81 282.78 750.00 Density (g/cm3) I 0.920 - 1.104 Single Stage Flash Data Original STO De-Contaminated GOR (scf(stb) 240 STO Density (g/cm3) 0.9196 I STO API Gravity 224 OBM Density (g/cm3) @60°F Table 16: Calculated Fluid Properties Sample#: 1.10; CSB 14004-QA; OBc Sand; MD = 7405 ft; TVD = 4864 ft; TVDSS = -4782 ft I I I I I I I I I WCP Oilphase-DBR 27 Job #: 200400299 I I I I I I I I I I I I I I I I I I I ... Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay Obc Figure 11: Stock Tank Oil Chromatogram (Sample 1.10) Sample#: 1.10; CSB 14004-QA; OBe Sand; MO '" 7405 ft; TVO '" 4864 ft; TVOSS '" -4782 ft pA 700 ÔOO 500 4û0 300 200 100 10 20 30 4û 50 Figure 12: k-Plot for Equilibrium Check (Sample t 10) Sample# 1.10; CSB 14004-QA; OBe Sand; MD '" 7405 ft; TVO '" 4864 ft; TVOSS '" -4782 ft 250 . C3 200 .nC4 1.50 1.00 ëi. . C6 ... 0.50 'Ei '" ..... 0.00 050 1.00 1.50 250 200 1.50 1.00 050 000 0.50 1.00 1.50 200 2.50 300 WCP Oilphase-DElR 28 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay Obd Schlumbepgep Table 11: Summary of Results of Sample 1.01 Sample#: 1.01; CSB 14009-0A; OBd Sand; MD = 7493 ft; TVD = 4914 ft; TVDSS = -4832 ft Reservoir Conditions: Pressure: 2171 psia Temperature: 99 OF Summary of Fluid Properties: Bubble Point Pressure At Tres 1,951 pSla Gas-Oil Ratio Single-stage Flash: 259 scf/stb Total Differential Liberation: scf/stb Total Separator Flash: scf/stb Properties at GO°F STO °API Gas Gravity (Average) Single-stage STO: 20.6 0.654 Differential Liberation STO: Separator STO: Properties at Reservoir Conditions Viscosity: 14.44 cP Compressibillity (Co): 5.1 1O-6/psi Density: 0.875 glee Properties at Saturation Conditions Viscosity: 14.06 cP Compressibillity (Co): 5.2 1O-6/psi Density: 0.874 glee Formation Volume Factor @Pres & Tres @Psat & Tres Single-stage Flash: 1.105 1.106 Total Differential Liberation: Total Separator Flash: Note: Standard conditions are 14.696 psia and 60°F WCP Oilphase-DBR 29 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay Obd Schlumb8Pgep PVT Analysis on Sample#: 1.01; CSB 14009-QA; OBd Sand; MD = 7493 ft; TVD = 4914 ft; TVDSS = -4832 ft Constant Composition Expansion at Tres The CCE study was initiated by charging a sub-sample of live reservoir fluid into the PVT cell at a reservoir temperature of 99°F and at a pressure of 9,015 psia. Sequential pressure decrease in steps and the corresponding volume changes are presented in Table 18. The pressure-volume (P-V) plots of the CCE data are presented in Figure 13. The intersection of the single-phase and two-phase lines in the P-V plot and the visual observation was used to define the bubblepoint. For the subject fluid, the bubblepoint was determined to be 1,951 psia at the reservoir temperature of 99 of. Also, calculated relative volume and oil compressibility is presented in Table 18. As seen in the table, the compressibility of this oil is 5.2 x 1 Oe-61jpsia at the saturation pressure. Table 18: Constant Composition Expansion at 99°F (Sample 1.01) Sample#: 1.01; CSB 14009-QA; OBd Sand; MD = 7493 ft; TVD = 4914 ft; TVDSS = -4832 ft Pressure Relative Vol % Liquid % Liquid Liquid Density Y Function Compressibility (psia) (Vr=VNsat) (VlNsat) (VINtotal) (g/cm3) (1 O·G/psi a) 1 9015 0.9678 0.9034 4.2 2 7017 0.9761 0.8957 4.4 3 5015 0.9850 0.8875 47 4 4015 0.9897 0.8833 4.8 5 3015 0.9946 0.8790 5.0 6 2817 0.9956 0.8781 5.0 7 2618 0.9966 0.8772 5.1 8 2418 0.9976 0.8764 5.1 Pi 2171 0.9989 0.8752 5.1 10 2015 0.9997 0.8745 5.1 Pb 1951 1.0000 100.0 100.0 0.8743 5.2 12 1857 1.0093 99.9 99.0 5.5 13 1711 1.0269 997 97.1 5.2 14 1481 1.0653 99.4 93.3 4.9 15 1163 1.1584 98.9 85.4 4.3 16 880 1.3162 98.4 74.8 3.8 17 697 1.4909 98.1 65.8 37 18 523 1.7883 97.8 547 3.5 19 417 2.0960 97.7 46.6 3.4 WCP Oilphase-DBR 30 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay Obd SchlumbePlep WCP Oilphase-DBR Figure 13: Constant Composition Expansion at 9goF - Relative Volume Sample#: 1.01; CSB 14009-QA; OBd Sand; MD = 7493 ft; TVD = 4914 ft; TVDSS = -4832 ft 2.2 ( ~- ~-------- -~ -- -- ~- \ -~---- \ ~- -. -- -- ~ 2.0 1.8 ~ 1:1.. ~ 1.6 ~ G) E = Ci > G) .~ 14 ca -¡; a:: 1.2 1.0 0.8 o 6000 8000 10000 2000 4000 Pressure (psia) 31 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay Obd Schlumbepgep Reservoir Oil Viscosity at Tres The liquid phase viscosity was measured at the reservoir temperature of 99°F. These values as a function of selected pressure steps are summarized in Table 19. The liquid phase viscosity values are graphically presented in Figure 14. As seen in the figures and as expected, the viscosity values decrease with decreasing pressure up to the bubblepoint and increase with further reduction in pressure below the bubblepoint. Table 19: Reservoir fluid Viscosity 99°f (Sample 1.01) Sample#: 1.01; CSB 14009-QA; OBd Sand; MD = 7493 ft; TVD = 4914 ft; TVDSS = -4832 ft Pressure Viscosity @ Tres (psi a) (cP) 1 10033 36.1 2 9007 32.3 3 8013 28.8 4 7006 25.6 5 6011 22.6 6 5034 20.4 7 4532 19.2 8 4084 18.1 9 3544 17.0 10 3036 16.1 11 2545 15.1 Pi 2171 14.4 13 2022 14.1 14 1975 14.1 Pb 1951 14.1 16 1911 14.3 17 1675 15.8 18 1618 16.3 19 1564 16.6 20 1489 17.2 21 1397 18.0 22 1303 18.9 23 1154 20.6 24 927 23.6 25 753 27.4 STO 15 67.4 WCP Oilphase-OBR 32 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay Obd Schlumbepgep ~ E. ~ '¡;¡ 40 co U ell :; WCP Oilphase-DBR figure 14: Reservoir fluid Viscosity 9gof (Sample 1.01) Sample#: 1.01; CSB 14009-QA; OBd Sand; MD = 7493 ft; TVD = 4914 ft; TVDSS = -4832 ft 70 60 50 30 20 10 o 2000 4000 6000 Pressure (psial 8000 10000 12000 33 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay Obd Scblumberger Reservoir Oil Viscosity at 60°F The liquid phase viscosity was measured at the reservoir temperature of GO°F. These values as a function of selected pressure steps are summarized in Table 20. The liquid phase viscosity values are graphically presented in Figure 15. As seen in the figures and as expected, the viscosity values decrease with decreasing pressure up to the bubblepoint, whose exact value cannot be determined by this viscosity test, and increase with further reduction in pressure below the bubblepoint. Table 20: Reservoir Fluid Viscosity 60°F (Sample 1.01) Sample#: 1.01; CSB 14009-QA; OBd Sand; MD = 7493 ft; TVD = 4914 ft; TVDSS = -4832 ft Pressure Viscosity @Tres (psi a) (cP) 1 3008 45.1 2 2487 42.6 3 2016 40.6 4 1414 42.0 5 1035 46.4 6 597 87.7 STO 14.696 276.4 WCP Oilphase-DBR 34 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay Obd Scblumberger Figure 15: Reservoir Fluid Viscosity 60°F (Sample 1.01) Sample#: 1.01; CSB 14009-0A; OBd Sand; MD = 7493 ft; TVD = 4914 ft; TVDSS = -4832 ft 320 ) 0 0 0 ) 0 > 270 220 ã:' .£ ~ ïii 170 CI .... en :;: 120 70 20 o 3000 4000 1000 2000 Pressure (psia) WCP Oilphase-DBR 35 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay Obd SchlumbePlep Reservoir Oil Viscosity at 75°F The liquid phase viscosity was measured at the temperature of 75°F. These values as a function of selected pressure steps are summarized in Table 21. The liquid phase viscosity values are graphically presented in Figure 16. As seen in the figures and as expected, the viscosity values decrease with decreasing pressure up to the bubblepoint, whose exact value cannot be determined by this viscosity test, and increase with further reduction in pressure below the bubbleooint. Table 21: Reservoir Fluid Viscosity 75°F (Sample 1.01) Sample#: 1.01; CSB 14009-QA; OBd Sand; MD = 7493 ft; TVD = 4914 ft; TVDSS = -4832 ft Pressure Viscosity@ Tres (psia) (cP) 1 5014 37.1 2 3014 28.4 3 2518 26.7 4 2171 25.4 5 2016 24.9 6 1408 27.3 7 1013 32.5 8 424 52.3 STO 14.696 118.4 WCP Oilphase-DBR 36 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay Obd Scblumberger Figure 16: Reservoir Fluid Viscosity 75°F (Sample 1.01) Sample#: 1.01; CSB 14009-QA; OBd Sand; MD = 7493 ft; TVD = 4914 ft; TVDSS = -4832 ft 140 ) 0 ) > 0 )0 0 120 100 ~ E. ~ .¡¡¡ 80 CI Ii! :;: 60 40 20 o 2000 5000 6000 1000 3000 Pressure (psia) 4000 WCP Oilphase-DBR 37 Job #: 200400299 I I I I I I I I I I I I I I I I I I I CI ¡ent: Well: BP Z210PB1 Field: Sand: Prudhoe Bay Obd SchlumbePlep Reservoir Oil Viscosity at 150°F The liquid phase viscosity was measured at the temperature of 150°F. These values as a function of selected pressure steps are summarized in Table 22. The liquid phase viscosity values are graphically presented in Figure 17. As seen in the figures and as expected, the viscosity values decrease with decreasing pressure up to the bubblepoint. whose exact value cannot be determined by this viscosity test. and increase with further reduction in pressure below the bubblepoint. Table 22: Reservoir Fluid Viscosity 150°F (Sample 1.01) Sample#: 1.01; CSB 14009-QA; OBd Sand; MD = 7493 ft; TVD = 4914 ft; TVDSS = -4832 ft Pressure Viscosity @ Tres {psial {cPI 1 7834 15.1 2 3016 9.2 3 2513 8.9 4 2171 8.8 5 2021 8.8 6 1479 9.4 7 1099 10.5 8 661 13.4 STO 14.696 23.8 WCP Oilphase-DBR 38 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: Well: BP Z210PB1 Field: Sand: SchlumbePlep Prudhoe Bay Obd Figure 17: Reservoir Fluid Viscosity 150°F (Sample 1.01) Sample#: 1.01; CSB 14009-QA; OBd Sand; MD = 7493 ft; TVD = 4914 ft; TVDSS = -4832 ft 25 '"' 0 0 0 0 o 0 20 ~ E. ~ .¡;¡ 15 o u en :;: 10 5 o 2000 4000 6000 8000 Pressure (psia) WCP Oilphase-DBR 39 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay Obd Schlumbepgep Reservoir Oil Viscosity at 200°F The liquid phase viscosity was measured at the reservoir temperature of 200°F. These values as a function of selected pressure steps are summarized in Table 23. The liquid phase viscosity values are graphically presented in Figure 18. As seen in the figures and as expected, the viscosity values decrease with decreasing pressure up to the bubblepoint. whose exact value cannot be determined by this viscosity test, and increase with further reduction in pressure below the bubblepoint. Table 23: Reservoir Fluid Viscosity 200°F (Sample 1.01) Sample#: 1.01; CSB 14009-QA; OBd Sand; MD = 7493 ft; TVD = 4914 ft; TVDSS = -4832 ft Pressure Viscosity@Tres (psia) (cP) 1 8017 9.1 2 3005 5.5 3 2519 5.1 4 2171 4.9 5 2019 4.8 6 1425 4.4 7 1032 5.0 8 583 6.2 STO 15 11.2 WCP Oilphase-DBR 40 Job #: 200400299 I I I I I I I I I I I I I I I I Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay Obd Scblumbepgep Figure 18: Reservoir Fluid Viscosity 200°F (Sample 1.01) Sample#: 1.01; CSB 14009-QA; OBd Sand; MO = 7493 ft; TVO = 4914 ft; TVOSS = -4832 ft 12 0 0 0 0 >0 0 10 ¡¡:- ~ ¡:. 'w 8 CI Co) en ::: 6 4 o 8000 10000 2000 4000 6000 Pressure (psia) WCP Oi/phase-DBR 41 Job #: 200400299 I I I I Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay DA Schlumbepgep I I I I I I I I I I I I I I I Table 24: Summary of Results of Sample 1.06 Sample#: 1.06; CSB 14007 -OA; OA Sand; MD = 7139 ft; TVD == 4711 ft; TVDSS = -4629 ft Reservoir Conditions: Pressure: 2100 pSla Temperature: 96 of Summary of Fluid Properties: Bubble Point Pressure At Tres 1,693 psi a Gas-Oil Ratio Single-stage Flash: 208 scf/stb Total Differential Liberation: scf Istb Total Separator Flash: scf/stb Properties at GO°F STO °API Gas Gravity (Average) Single-stage STD: 15.8 0.589 Differential Liberation STO: Separator STO: Properties at Reservoir Conditions Viscosity: 104.96 cP Compressibillity (Co): 5.7 1O-6/psi Density: 0.926 glee Properties at Saturation Conditions Viscosity: 97.80 cP Compressibillity (Co): 5.8 10%si Density: 0.924 glee Formation Volume Factor @Pres & Tres @Psat & Tres Single-stage Flash 1.066 1.068 Total Differential Liberation: Total Separator Flash: Note: Standard conditions are 14.696 psi a and 60°F WCP Oilphase-DBR 42 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay OA SchlumbePlep PVT Analysis on Sample#: 1.06; CSB 14007-QA; OA Sand; MD = 7139 ft; TVD = 4711 ft; TVDSS = -4629 ft Constant Composition Expansion at Tres The CCE study was initiated by charging a sub-sample of live reservoir fluid into the PVT cell at a reservoir temperature of 96°F and at a pressure of 9,015 psia. Sequential pressure decrease in steps and the corresponding volume changes are presented in Table 25. The pressure-volume (P-V plots of the CCE data are presented in Figure 19. The intersection of the single-phase and two-phase lines in the P-V plot and the visual observation was used to define the bubblepoint. For the subject fluid, the bubblepoint was determined to be 1,693 psia at the reservoir temperature of 96 of. Also, calculated relative volume and oil compressibility is presented in Table 25. As seen in the table, the compressibility of this oil is 5.8 x 1Oe-61/psia at the saturation pressure. Table 25: Constant Composition Expansion at 96°F (Sample 1.06) Sample#: 1.06; CSB 14007-QA; OA Sand; MD = 7139 ft; TVD = 4711 ft; TVDSS = -4629 ft Pressure Relative Vol % Liquid % Liquid Liquid Density Y Function Compressibility (psia) (Vr=VNsat) (VINsat) (VINtotal) (g/cm3) (10-6/psia) 1 9015 0.9616 0.9612 4.9 2 8016 0.9664 0.9564 5.0 3 7014 0.9713 0.9516 5.1 4 6015 0.9764 0.9467 5.3 5 5017 0.9816 0.9416 5.4 6 4015 0.9870 0.9365 5.5 7 3515 0.9897 0.9339 5.6 8 3016 0.9925 0.9313 5.6 9 2515 0.9953 0.9287 5.7 Pi 2100 0.9977 0.9265 5.7 11 1915 0.9987 0.9255 5.8 Pb 1693 1.0000 100.0 100.0 0.9243 5.8 13 1552 1.0106 99.8 98.8 8.56 14 1495 1.0161 99.7 98.2 8.22 15 1426 1.0239 99.6 97.3 7.85 16 1302 1.0417 99.4 95.5 7.20 17 1198 1.0608 99.3 93.6 6.80 18 1029 1.1042 99.0 89.6 6.19 19 915 1.1434 98.8 86.4 5.93 20 725 1.2384 98.5 79.5 5.60 21 598 1.3425 98.3 73.2 5.35 22 405 1.6116 98.1 60.9 5.20 23 274 2.0357 98.0 48.1 5.00 WCP Oilphase-DBR 43 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay OA ScblumbepgBP WCP Oilphase-DBR Figure 19: Constant Composition Expansion at 96°F - Relative Volume Sample#: 1.06; CS8 14007-QA; OA Sand; MD = 7139 ft; TVD = 4711 ft; TVDSS = -4629 ft 2.2 ( -- -- -------- -~_._-- --" -.---- .- --~~ -~ r------ ._~ ---..----.- f-------- ------- \ 1------ -- ~ '" 2.0 1.8 := a.. <! 1.6 ~ ~ G) E ::I Õ > G) .:: 1 A ... oa ãi a:: 1.2 1.0 0.8 o 8000 10000 2000 4000 6000 Pressure (psia) 44 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay OA Schlulbepgep Reservoir Oil Viscosity at Tres The liquid phase viscosity was measured at the reservoir temperature of 96°F. These values as a function of selected pressure steps are summarized in Table 26. The liquid phase viscosity values are graphically presented in Figure 20. As seen in the figures and as expected, the viscosity values decrease with decreasing pressure up to the bubblepoint and increase with further reduction in pressure below the bubblepoint. Table 26: Reservoir Fluid Viscosity 96°F (Sample 1.06) Sample#: 1.06; CSB 14007-QA; OA Sand; MD = 7139 ft; TVD = 4711 ft; TVDSS = -4629 ft Pressure Viscosity @ Tres {psi a} {cP} 1 9682 386.2 2 9052 349.0 3 7986 289.4 4 7083 247.6 5 6074 209.4 6 5057 174.6 7 4524 158.5 8 4078 147.9 9 3501 132.8 10 3084 124.5 11 2519 113.1 Pi 2100 105.0 Pb 1693 97.8 14 1607 103.0 15 1277 127.1 16 1092 145.1 17 851 173.4 18 631 210.9 19 456 255.9 STO 15 592.7 WCP Oi/phase-DBR 45 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay OA Schlumbepuep íi:' 400 E. i:' .¡¡¡ CI () iii :;: 300 WCP Oilphase-DBR Figure 20: Reservoir Fluid Viscosity 96°F (Sample 1.06) Sample#: 1.06; CSB 14007-0A; OA Sand; MD = 7139 ft; TVD = 4711 ft; TVDSS = -4629 ft 700 600 500 200 100 o o 8000 10000 2000 4000 6000 Pressure (psia) 46 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay OA Schlumb8Pg8P Reservoir Oil Viscosity at 60°F The liquid phase viscosity was measured at the reservoir temperature of 60°F. These values as a function of selected pressure steps are summarized in Table 27. The liquid phase viscosity values are graphically presented in Figure 21. As seen in the figures and as expected, the viscosity values decrease with decreasing pressure up to the bubblepoint, whose exact value cannot be determined by this viscosity test, and increase with further reduction in pressure below the bubblepoint. Table 27: Reservoir fluid Viscosity 60°f (Sample 1.06) Sample#: 1.06; CSB 14007-QA; OA Sand; MD = 7139 ft; TVD = 4711 ft; TVDSS == -4629 ft Pressure Viscosity @Tres (psia) (cP) 1 3028 535.8 2 2533 481.9 3 2030 438.8 4 1434 399.8 5 1040 410.5 6 639 727.2 7 15 3142.0 WCP Oilphase-DBR 47 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: Well: BP WOPB1 Field: Sand: Prudhoe Bay OA Scblumberger ii:" 2020 E ~ .¡;; c Ii! :; 1520 WCP Oilphase-DBR Figure 21: Reservoir Fluid Viscosity 60°F (Sample 1.06) Sample#: 1.06; CSB 14007-QA; OA Sand; MD == 7139 ft; TVD = 4711 ft; TVDSS == -4629 ft 3520 ) 0 ::> 0 ) u 3020 2520 1020 520 20 o 3000 4000 1000 2000 Pressure (psia) 48 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay OA Scblombepuep Reservoir Oil Viscosity at 75°F The liquid phase viscosity was measured at the reservoir temperature of 75°F. These values as a function of selected pressure steps are summarized in Table 28. The liquid phase viscosity values are graphically presented in Figure 22. As seen in the figures and as expected, the viscosity values decrease with decreasing pressure up to the bubblepoint, whose exact value cannot be determined by this viscosity test, and increase with further reduction in pressure below the bubblepoint. Table 28: Reservoir Fluid Viscosity 75°F (Sample 1.06) Sample#: 1.06; CSB 14007-QA; OA Sand; MD = 7139 ft; TVD = 4711 ft; TVDSS = -4629 ft Pressure Viscosity@Tres (psia) (cP) 1 3014 311.1 2 2523 287.9 3 2020 264.1 4 1433 236.7 5 1023 260.0 6 620 321.4 7 15 1411.0 WCP Oilphase-DBR 49 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay OA Scblumbepgep 1000 ã: E. ~ 800 .¡¡¡ CI u en ;;: 600 WCP Oilphase-DBR Figure 22: Reservoir Fluid Viscosity 75°F (Sample 1.06) Sample#: 1.06; CS8 14007-QA; OA Sand; MD = 7139 ft; TVD = 4711 ft; TVDSS = -4629 ft 1600 0 ) ) ) 0 0 1400 1200 400 200 o o 2000 Pressure (psia) 3000 4000 1000 50 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay OA SchlumbePlep Reservoir Oil Viscosity at 150°F The liquid phase viscosity was measured at the reservoir temperature of 150°F. These values as a function of selected pressure steps are summarized in Table 29. The liquid phase viscosity values are graphically presented in Figure 23. As seen in the figures and as expected, the viscosity values decrease with decreasing pressure up to the bubblepoint whose exact value cannot be determined by this viscosity test and increase with further reduction in pressure below the bubblepoint. Table 29: Reservoir Fluid Viscosity 150°F (Sample 1.06) Sample#: 1.06; CSB 14007-QA; OA Sand; MD = 7139 ft; TVD = 4711 ft; TVDSS = -4629 ft Pressure Viscosity @Tres {psi a) (cP) 1 3020 37.0 2 2529 34.8 3 2032 31.6 4 1465 32.0 5 1087 32.5 6 637 37.8 7 15 79.8 WCP Oilphase-DBR 51 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay OA Scblumberger Figure 23: Reservoir Fluid Viscosity 150°F (Sample 1.06) Sample#: 1.06; CSB 14007-0A; OA Sand; MD = 7139 ft; TVD = 4711 ft; TVDSS = -4629 ft 90 0 ) 0 0 0 :> 80 70 íi:" 60 E. ~ 'w o &J :> 50 40 30 20 o 1000 2000 Pressure (psia) 3000 4000 WCP Oilphase-DBR 52 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay OA Schlumbepgep Reservoir Oil Viscosity at 200°F The liquid phase viscosity was measured at the reservoir temperature of 200°F. These values as a function of selected pressure steps are summarized in Table 30. The liquid phase viscosity values are graphically presented in Figure 24. As seen in the figures and as expected, the viscosity values decrease with decreasing pressure up to the bubblepoint, whose exact value cannot be determined by this viscosity test, and increase with further reduction in pressure below the bubblepoint. Table 30: Reservoir Fluid Viscosity 200°F (Sample 1.06) Sample#: 1.06; CSB 14007-QA; OA Sand; MD = 7139 ft; TVD = 4711 ft; TVDSS = -4629 ft Pressure Viscosity @ Tres (psia) (cP) 1 3012 14.6 2 2515 14.0 3 2009 12.2 4 1414 12.4 5 1015 12.9 6 609 14.8 STO 15 25.3 WCP Oilphase-DBR 53 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay OA SchlulbePlep Figure 24: Reservoir Fluid Viscosity 200°F (Sample 1.06) Sample#: 1.06; CSB 14007-QA; OA Sand; MD = 7139 ft; TVD = 4711 ft; TVDSS = -4629 ft 30 ::> 0 ) 0 ) 0 25 ii:" E. ~ .¡¡¡ 20 o &J :;: 15 10 o 1000 3000 4000 2000 Pressure (psial WCP Oilphase-DBR 54 Job #: 200400299 I I Client: Well: BP Z2lOPB1 Field: Sand: Prudhoe Bay LOWER Oba ScblumbePler I I I I I I I I I I I I I I I I I Table 31: Summary of Results of Sample 1.09 Sample#: 1.09; CSB 14006-QA; DBa_Lower Sand; MD = 7263 ft; TVD = 4783 ft; TVDSS = -4701 ft Reservoir Conditions: Pressure: 2102 psia Temperature: 97 of Summary of Fluid Properties: Bubble Point Pressure At Tres 1,680 pSIa Gas-Oil Ratio Single-stage Flash: 194 scf!stb Total Differential Liberation: scf!stb Total Separator Flash: scf!stb Properties at GO°F STO °API Gas Gravity (Average) Single-stage STO: 16.0 0.596 Differential Liberation STO: Separator STO: Properties at Reservoir Conditions Viscosity: 98.7 4 cP Compressibillity (Co): 4.8 1O-6/psi Density: 0.916 g/cc Properties at Saturation Conditions Vi scosíty: 91.65 cP Compressibillity (Co): 4.9 1 0-6/psi Density: 0.914 g/cc Formation Volume Factor @Pres & Tres @Psat & Tres Single-stage Flash: 1.075 1.077 Total Differential Liberation: Total Separator Flash: Note: Standard conditions are 14.696 psia and 60°F WCP Oilphase-DBR 55 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: Well: BP Z21oPB1 Field: Sand: Prudhoe Bay LOWER Dba ScblumbePlep PVT Analysis on Sample#: 1.09; CSB 14006-0A; DBa_Lower Sand; MD = 7263 It; TVD = 4783ft; TVDSS = -4701 It Constant Composition Expansion at Tres The CCE study was initiated by charging a sub-sample of live reservoir fluid into the PVT cell at a reservoir temperature of 97.0°F and at a pressure of 9,015 psia. Sequential pressure decrease in steps and the corresponding volume changes are presented in Table 32. The pressure-volume (P-V) plots of the CCE data are presented in Figure 25. The intersection of the single-phase and two-phase lines in the P-V plot and the visual observation was used to define the bubblepoint. For the subject fluid, the bubblepoint was determined to be 1,680 psia at the reservoir temperature of 97.0 oF. Also, calculated relative volume and oil compressibility is presented in Table 32. As seen in the table, the compressibility of this oil is 4.9 x lOe-6 1 /psia at the saturation pressure. Table 32: Constant Composition Expansion at 97°F (Sample 1.09) Sample#: 1.09; CSB 14006-QA; DBa_Lower Sand; MO = 7263 ft; TVO = 4783 ft; TVOSS = -4701 ft Pressure Relative Vol % Liquid % Liquid Liquid Density Y Function Compressibility (psia) (Vr=VNsat) (VINsat) (VINtotal) (g/cm3) (10·6/psia) 1 9015 0.9716 0.941 3.1 2 8015 0.9747 0.938 3.3 3 7015 0.9780 0.935 3.5 4 6015 0.9815 0.932 3.7 5 5015 0.9853 0.928 4.0 6 4015 0.9894 0.924 4.2 7 3015 0.9937 0.920 4.5 Pi 2102 0.9980 0.916 4.8 9 1715 0.9998 0.915 4.9 Pb 1680 1.0000 100.0 100.0 0.914 4.9 11 1575 1.0162 99.8 98.2 411 12 1470 1.0350 99.7 96.3 4.08 13 1349 1.0608 99.4 93.7 4.04 14 1308 1.0708 99.3 92.7 4.02 15 1143 1.1181 98.7 88.2 3.98 16 1011 1.1675 98.0 84.0 3.95 17 817 1.2691 97.5 76.8 3.93 18 675 1 .3806 97.2 70.4 3.91 19 528 1.5608 97.2 62.3 3.89 20 443 1.7224 97.1 56.4 3.87 21 361 1.9482 97.1 49.8 3.85 22 331 2.0595 97.0 47.1 3.85 WCP Oilphase-DBR 56 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay LOWER Oba Scblumbepuep Figure 25: Constant Composition Expansion at 97°F - Relative Volume Sample#: 1.09; CSB 14006-QA; OBa_Lower Sand; MD = 7263 ft; TVD = 4783 ft; TVDSS = -4701 ft WCP Oilphase-DBR 2.2 ( c--- ~-------- f-----. .-- -- -- ---- ----------- f----- -- -~~~- ~ -- --- ------ ---- ----- - 2.0 1.8 ~ a.. ~ 1.6 ~ II> e ::0 c; > .~ 14 ë 'ii a: 1.2 1.0 0.8 o 2000 6000 8000 10000 4000 Pressure (psia) 57 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: Well: BP Z21oPB1 Field: Sand: Prudhoe Bay LOWER Oba Schlumberler Reservoir Oil Viscosity at Tres The liquid phase viscosity was measured at the reservoir temperature of 97°F. These values as a function of selected pressure steps are summarized in Table 33. The liquid phase viscosity values are graphically presented in Figure 26. As seen in the figures and as expected, the viscosity values decrease with decreasing pressure up to the bubblepoint and increase with further reduction in pressure below the bubblepoint. Table 33: Reservoir Fluid Viscosity 97°F (Sample 1.09) Sample#: 1.09; CSB 14006-QA; DBa_Lower Sand; MD = 7263 ft; TVD = 4783 ft; TVDSS = -4701 ft Pressure Viscosity @ Tres (psia) (cP) 1 9018 304.0 2 8002 260.2 3 7051 225.6 4 6078 190.5 5 5103 163.1 6 4548 149.1 7 4070 137.8 8 3524 126.0 9 3064 117.8 10 2510 106.8 Pi 2102 98.7 12 2028 97.3 13 1892 94.8 14 1717 92.3 Pb 1680 91.7 16 1564 96.9 17 1434 102.7 18 1295 108.6 19 1176 116.1 20 906 132.2 21 541 192.3 STO 15 459.9 WCP Oilphase-DBR 58 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay LOWER Dba Schlumberger figure 26: Reservoir fluid Viscosity 97°f (Sample 1.09) Sample#: 1.09; CSB 14006-0A; DBa_Lower Sand; MD == 7263 ft; TVD == 4783 ft; TVDSS == -4701 ft 300 ~ E ;:- .¡;¡ 0 :¡¡ :;: 200 WCP Oilphase-DBR 500 400 100 o o 6000 8000 10000 2000 4000 Pressure (psial 59 Job #: 200400299 I I I I I I I Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay Obc Schlumbepgep Table 34: Summary of Results of Sample 1.10 Sample#: 1.10; CSB 14004-QA; OBc Sand; MD = 7405 ft; TVD = 4864 ft; TVDSS = -4782 ft I Reservoir Conditions: Pressu re: 2137 psia Temperature: 98 OF Summary of Fluid Properties: Bubble Point Pressure AtTres 1,861 pSI a Gas-Oil Ratio Si ngle-stage Flash: 240 scf/stb Total Differential Liberation: scf/stb Total Separator Flash: scf/stb Properties at 60°F STO °API Gas Gravity (Average) Single-stage STO 22.4 0.681 Differential Liberation STO: Separator STO: Properties at Reservoir Conditions Viscosity: 9.94 cP Compressibillity (Co): 6.0 1O"6¡psi Density: 0.854 g/cc Properties at Saturation Conditions Vi scosity: 9.59 cP Compressibillity (Co): 6.1 10-6/psi Density: 0.853 g/cc Formation Volume Factor @Pres & Tres @Psat & Tres Single-stage Flash 1.119 1.120 Total Differential Liberation: Total Separator Flash: I I I I I Note: Standard conditions are 14.696 psia and 60°F I I I I I I WCP Oilphase-DBR 60 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay Obc Schlumberger PVT Analysis on Sample#: 1.10; CSB 14004-QA; OBc Sand; MD = 7405 ft; TVD = 4864 ft; TVDSS = -4782 ft Constant Composition Expansion at Tres The CCE study was initiated by charging a sub-sample of live reservoir fluid into the PVT cell at a reservoir temperature of 98.0°F and at a pressure of 14,515 psia. Sequential pressure decrease in steps and the corresponding volume changes are presented in Table 35. The pressure-volume (P-V) plots of the CCE data are presented in Figure 27. The intersection of the single-phase and two-phase lines in the P-V plot and the visual observation was used to define the bubblepoint. For the subject fluid, the bubblepoint was determined to be 1,861 psia at the reservoir temperature of 98.0 OF. Also, calculated relative volume and oil compressibility is presented in Table 35. As seen in the table, the compressibility of this oil is 6.1 x 10e-6 1/psia at the saturation pressure. Table 35: Constant Composition Expansion at 98°F (Sample 1.10) Sample#: 1.10; CSB 14004-QA; OBc Sand; MD = 7405 ft; TVD = 4864 ft; TVDSS = -4782 ft Pressure Relative Vol % Liquid % Liquid Liquid Density Y Function Compressibility (psia) (Vr=VNsat) (VINsat) (VINtotal) (g/cm3) (10-6/psia) 1 14515 0.9428 0.904 3.4 2 9015 0.9633 0.885 4.4 3 6515 0.9746 0.875 5.0 4 5715 0.9786 0.871 5.1 5 5015 0.9822 0.868 5.3 6 4615 0.9843 0.866 5.4 7 3815 0.9886 0.862 5.6 8 3515 0.9903 0.861 5.7 9 2315 0.9973 0.855 6.0 Pi 2137 0.9983 0.854 6.0 Pb 1861 1.0000 100.0 100.0 0.853 6.1 12 1787 1.0082 99.9 99.0 5.03 13 1545 1.0446 99.4 95.2 4.58 14 1220 1.1323 98.8 87.3 3.97 15 865 1.3301 98.1 73.7 3.49 16 666 1.5446 97.6 63.2 3.29 17 524 1.8202 97.3 53.4 3.11 18 470 1.9905 97.1 48.8 2.99 WCP Oilphase-DBR 61 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay Obc Scblumb8PI8P WCP Oilphase-DBR Figure 27: Constant Composition Expansion at 98°F - Relative Volume Sample#: 1.10; CSB 14004-QA; OBc Sand; MD = 7405 ft; TVD = 4864 ft; TVDSS = -4782 ft 2.2 -- t----- --~ ,- f----I-- -- j----- --~ .--t---- ~ f--- \ j------ -- -- --- '" 2.0 1.8 :ë a.. ~ 1.6 ~ CD e = c; > .~ 14 ë ã; a: 1.2 1.0 0.8 o 2000 4000 6000 8000 10000 12000 14000 16000 Pressure (psia) 62 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay Obc Schlumbepgep Reservoir Oil Viscosity at Tres The liquid phase viscosity was measured at the reservoir temperature of 98°F. These values as a function of selected pressure steps are summarized in Table 36. The liquid phase viscosity values are graphically presented in Figure 28. As seen in the figures and as expected, the viscosity values decrease with decreasing pressure up to the bubblepoint and increase with further reduction in pressure below the bubblepoint. Table 36: Reservoir Fluid Viscosity 98°F Sample#: 1.10; CSB 14004-QA; OBc Sand; MD == 7405 ft; TVD == 4864 ft; TVDSS == -4782 ft Pressure Viscosity @ Ires {psi a) (cP) 1 10018 22.20 2 9231 20.43 3 8073 18.09 4 7064 16.34 5 6083 14.82 6 5051 13.44 7 4544 12.69 8 4066 12.08 9 3548 11.55 10 3139 10.99 11 2535 10.34 Pi 2137 9.94 13 2025 9.80 Pb 1861 9.59 15 1818 9.60 16 1706 9.78 17 1605 10.17 18 1495 10.53 19 1362 11.17 20 1269 11.53 21 1161 1213 22 934 13.11 23 721 14.69 24 371 19.28 STO 15 34.90 WCP Oilphase-DBR 63 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: Well: BP Z210PB1 Field: Sand: Prudhoe Bay Obc Schlu.mbePler Figure 28: Reservoir Fluid Viscosity 98°F Sample#: 1.10; CSB 14004-0A; OBc Sand; MD = 7405 ft; TVD = 4864 ft; TVDSS = -4782 ft 40 30 ii:" E. ~ .¡¡¡ 20 CI I:) en :; 10 o o 2000 8000 10000 12000 4000 6000 Pressure (psia) WCP Oilphase-DBR 64 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: Well: Installation: BP Z210PB1 Nabors 7ES Field: Sand: Job#: Prudhoe Bay Scblumberger 200400299 API Gravity Bg Bo CCE DV GLR GOR LO n OBM P Pb PV Pi R Rs T V Vr STL STO %,w/w Z Appendix A: Nomenclature and Definitions American Petroleum Institute gravity Gas formation volume factor Oil formation volume factor Constant composition Expansion Differential Vaporization Gas Liquid Ratio Gas Oil Ratio Live Oil Number of moles Oil Based Mud Absolute pressure Bubble point pressure Pressure-Volume Method Initial Reservoir Pressure Universal gas constant Solution gas oil ratio Temperature Volume Relative volume Stock Tank Liquid Stock Tank Oil Weight Percent Gas deviation factor Dry Gross Heating Value is defined as the total energy transferred as heat in an ideal combustion reaction at a standard temperature and pressure in which all water formed appears as liquid. Wet Gross Heating Value is defined as the total energy transferred as heat in an ideal combustion reaction of water saturated gas at a standard temperature and pressure in which all water formed appears as liquid. Molar masses, densities and critical values of pure components are from CRC handbook of Chemistry and Physics and those of pseudo components are from Katz data. Gas viscosity is calculated from the correlation of Carr, Kobayshi and Burrows as given in the "Phase Behavior of Oilfield Hydrocarbon Systems" by M.B. Standing Compressibility in constant mass study is obtained from mathematical derivation of relative volume. Gas gravity is calculated from composition using the perfect gas equation (Gas deviation factor, Z=1) The Stiff and Davis Stability Index is an extension of the Langlier Index and is used as an indicator of the calcium carbonate scaling tendencies of oil field brine. · A positive index indicates scaling tendencies. · A negative index indicates corrosive tendencies. An index of zero indicates the water is in chemical equilibrium and will neither deposit nor dissolve calcium carbonates. WCP Oilphase-DBR 65 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: Well: Installation: WCP Oilphase-DBR BP Field: Z210PB1 Sand: Nabors 7ES Job #: 200400299 Appendix B: Molecular Weights and Densities Used Prudhoe Bay Schlumbepgep Components MW Density (glee) CO2 44.01 0.827 H2S 34.08 0.993 N2 28.013 0.808 C1 16.043 0.300 C2 30.07 0.356 C3 44.097 0.508 I-C4 58.124 0.567 N-C4 58.124 0.586 I-C5 72.151 0.625 N-C5 72.151 0.631 C6 84 0.660 MCYC-C5 84.16 0.753 BENZENE 78.11 0.884 CYCL-C6 84.16 0.781 C7 96 0.688 MCYCL-C6 98.19 0.773 TOLUENE 92.14 0.871 C8 107 0.749 C2-BENZEN 106.17 0.870 M&P-XYLEN 106.17 0.866 O-XYLENE 106.17 0.884 C9 121 0.768 C10 134 0.782 C11 147 0.793 C12 161 0.804 C13 175 0.815 C14 190 0.826 C15 206 0.836 C16 222 0.843 C17 237 0.851 C18 251 0.856 C19 263 0.861 C20 275 0.866 C21 291 0.871 C22 300 0.876 C23 312 0.881 C24 324 0.885 C25 337 0.888 C26 349 0.892 C27 360 0.896 C28 372 0.899 C29 382 0.902 66 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: Well: Installation: BP Z210PB1 Nabors 7ES Field: Sand: Job#: Prudhoe Bay Scblumbørglr 200400299 Appendix C: EOUIPMENT fluid Preparation and Validation The opening pressure of the cylinder is measured using a Heise pressure gauge soon after the sample arrives in the laboratory. Subsequently, the sample bottle is pressurized to the reservoir pressure using water-glycol mixture at the bottomside of the piston cylinder. Custom made heating jacket is wrapped around the cylinder to heat the sample bottle to the reservoir temperature. The sample bottle is then placed into a rocking stand and rocked for 5 days to homogenize the reservoir fluid. Live reservoir fluid analysis is necessary in the sample validation process as well as during the completion of various fluid studies. A description of the experimental equipment used for these analysis follows. All live fluid analyses are completed with a JEFRI Gasometer. This unit in conjunction with GC analysis (see below) provides the full fluid compositional analysis, GOR, density at sampling P& T corrected to standard conditions. The JEFRI gasometer consists of a motor-driven piston in a stationary cylinder. The piston displacement is monitored to determine the swept volume of the cylinder. The cylinder pressure is automatically held at ambient pressure. Piston motion is tracked by a linear encoder, which is subsequently, converted to measure the gas volume in the cylinder. The total Gasometer volume is 10 L. The evolved gas can be re-circulated through the system to facilitate equilibrium at a maximum flow rate of 40 L/hr. The operating pressure of the Gasometer is ambient pressure (up to a maximum of 40 psia) and the operating temperature ranging from room temperature to 40°C. Following the flash of the live fluid sample to ambient conditions in the gasometer, compositional analysis of residual hydrocarbon liquid and evolved gas phase is conducted using gas chromatography (GC). Analysis of hydrocarbon liquids is conducted using an HP6890 liquid injection gas chromatograph equipped with flame ionization detector (FID). In this system, separation of individual components is carried out in a 30m long, 530mm diameter "Megabore" capillary column made of fused silica with 2.6-micrometer thick methyl silicone as the stationary phase. The operating temperature range of the stationary phase is 60 to 400°C. Over this temperature range, the components eluted are from C, to C36 along with naphthenes and aromatics components. Based on the physical properties, these components are retarded in a segregated fashion by the stationary phase during the flow of carrier gas (helium) through the column. With prior knowledge of the amount of "retention" for known compounds contained in calibration standards, the same compounds can be identified in the unknown hydrocarbon sample by matching "retention" times. The relative concentration of each component is determined by the concentration of ions hitting the FID upon the elution of each component. The analysis of hydrocarbon gases is carried out using an HP6890 gas injection GC equipped with two separation columns. The first column is a combination of a 100 mesh packed column and 100 mesh molecular sieve using high purity helium as a carrier gas. The molecular sieve is used to achieve separation of the light gaseous components (nitrogen, oxygen, and methane) while the packed column serves to separate ethane, propane, butanes, pentanes, and hexanes along with carbon dioxide and hydrogen sulfides. The second column is a packed column as described previously in liquid analysis. This column is capable of achieving separation of components up to C12+, along with the associated naphthenes and aromatics that are lumped into the C6+ fraction during analysis and reporting. Components up to C4 are analyzed using a thermal conductivity detector (TCD) while the C5+ components are analyzed for using a FID detector. The instrument has programmable air actuated multiport valves that allow the flow of the sample mixture to be varied between the two columns, and hence, allowing for the correct separation and analysis of the injected gas. fluid Volumetric (PVT) and Viscosity Equipment WCP Oilphase-DBR 67 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: BP Field: Well: Z210PB1 Sand: Installation: Nabors 7ES Job #: 200400299 The preliminary saturation pressure, constant composition expansion (CCE), differential vaporization (DV), multi-stage separation tests (MSST) are measured using a pressure-volume-temperature (PVT) apparatus. The PVT apparatus consists of a variable volume, visual JEFRI PVT cell. The main component of the cell consists of a Pyrex glass cylinder 15.2-cm long with an internal diameter of 3.2 cm. An especially designed floating piston and a magnetically coupled impeller mixer are mounted inside the Pyrex cylinder to allow for mercury-free operation. The bottom section of the piston is furnished with o-rings to isolate the hydraulic fluid from the cell content. The piston allows liquid level measurements as small as 0.005 cc. The magnetically coupled impeller mixer, mounted on the bottom end cap of the PVT cell, allow quick equilibration of the hydrocarbon fluid. The effective volume of the cell is approximately 120 cc. The Pyrex cylinder is housed inside a steel shell with vertical tempered glass plates to allow visual observation of the internal tube contents. Prudhoe Bay Scblumbepgep A variable volume JEFRI displacement pump controls the volume, and hence, the pressure of the fluids under investigation by means of injection or withdrawal of transparent hydraulic fluid connected to the floating piston from the top of the JEFRI PVT cell. The same hydraulic fluid is also connected to the outer steel shell to maintain a balanced differential pressure on the Pyrex cylinder. The PVT cell is mounted on a special bracket, which can be rotated 360°. The bracket along with the PVT cell is housed inside a temperature controlled, forced air circulation oven. The cell temperature is measured with a platinum resistance thermal detector (RTD) and displayed on a digital indicator with an accuracy of 0.2°F. The cell pressure is monitored with a calibrated digital Heise pressure gauge precise to ± 0.1 % of full scale. The temperature and pressure ratings of this PVT system are 15,000 psi (103 MPa) and 360°F (182°C). The fluid volume in the PVT cell is determined using a cathetometer readable to the nearest 0.01 mm. The cathetometer is equipped with a high-resolution video camera that minimizes parallax in readings and uses a high- resolution encoder producing both linear and volumetric readings. The height measurements by the cathetometer have been precisely calibrated with the total cell volume prior to the start of the test. The floating piston is designed in the shape of a truncated cone with gradually tapered sides. which allows measurement of extremely small volumes of liquid (0.005 cc) corresponding to roughly 0.01 % of the cell volume. The viscosity of the live reservoir fluid is measured at the reservoir temperature and pressure conditions using Cambridge SPL440 electromagnetic viscometer. which consists of one cylindrical cell containing the fluid sample and a piston located inside the cylinder. The piston is moved back and forth through the fluid by imparting an electromagnetic force on the piston. Viscosity is measured by the motion of the piston, which is impeded by viscous flow around the annulus between the piston and the sample cylinder wall. Various sizes of pistons are used to measure the viscosity of various fluids having different levels of viscosity. The temperature is maintained at the experimental condition using a re-circulating fluid heating system. The internal temperature is monitored using an internal temperature probe. The temperature rating of the viscometer is 190°C and pressure rating is 15,000 psig. The accuracy is ±1.5% of full scale for each individual piston range. The total volume of fluid sample required for viscosity measurement is 5 cc. A cylindrical piston cell (carrier chamber) with a maximum internal volume of 25 mL is attached at the top of the viscometer. The purpose of this cell is to allow the operator to conduct the differential vaporization pressure steps within the viscometer. The back and forth motion of the piston within a narrow clearance provides sufficient agitation to achieve phase equilibration and allow gases to escape and accumulate at the top of the carrier chamber. The heating jacket is wrapped around the viscometer and the carrier chamber and maintains experimental temperature uniformly throughout the system. WCP Oilphase-DBR 68 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: BP Field: Well: Z210PB1 Sand: Installation: Nabors 7ES Job #: 200400299 The JEFRI PVT cell is also equipped with fiber optic light transmittance probes to measure the onsets of hydrocarbon solids nucleation (OHSP) due to changes in the temperature, pressure and/or composition. These fiber optic probes are mounted across the windows of the visual cell. The principle behind the measurement is based on the transmittance of a laser light in the near infra red (NIR) wavelength through the test fluid undergoing temperature. pressure or the fluid composition changes. In this system, a computerized pump is controlled to maintain the system pressure during isobaric temperature sweeps for wax nucleation. isothermal pressure drop and/or isobaric injections of precipitating solvents for asphaltene nucleation studies. The process variables (i.e.. temperature. pressure, solvent volume. time and transmitted light power level) are recorded and displayed from the detector. The fiber optic light transmittance system referred to here that detects the conditions of OHSP is termed as the light scattering system (LSS). Prudhoe Bay Schlumbepgep High pressure filters are also used during the asphaltene nucleation study to quantify the amount of asphaltene in the fluid at the specified conditions. The filter manifold used is rated for 10.000 psia. The filter assembly consists of two plates screwed together with the hydrophobic filter sandwiched between them. WCP Oilphase-DBR 69 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: Well: Installation: BP Z210PB1 Nabors 7ES Field: Sand: Job #: Prudhoe Bay Schlumberger 200400299 Appendix D: PROCEDURE fluids Preparation and Validation After homogenizing, a small portion of the single-phase reservoir fluid is first subjected to a single stage flash experiment to determine flash Gas-Oil-ratio (GOR). The flashing is conducted from some pressure above the bubblepoint pressure at reservoir temperature into an atmospheric Gasometer and measuring the corresponding volumes of gas and liquid. The atmospheric flash also provides parameters such as GOR and stock tank oil density. The flashed fluids (gas and liquid) are then subjected to compositional analysis using gas chromatographic technique. Subsequently, live oil composition is calculated based on the measured gas and liquid compositions and GOR values. In addition, a sub-sample taken from each cylinder is isobarically transferred into the PVT cell at the reservoir temperature. Subsequently, a quick P-V relationship is established to determine the saturation pressure. Constant Composition Expansion Procedure A sub-sample of the test fluid is initially charged to the PVT apparatus and the system temperature stabilized at the reservoir temperature. The CCE experiment is then conducted by incrementally reducing the pressure from some pressure above the bubblepoint pressure to a pressure well below the bubblepoint pressure in a number of discrete steps. At each pressure step, the magnetic stirrer is used to make sure that the subject fluid achieved equilibrium. Total fluid volume (with visual observation of a single or two phase condition in the cell) is measured at each pressure stage, and subsequently, a pressure-volume (P-V) plot is created identifying the phase state at each P-V condition. The intersection of the two lines plotted using the pressure and volume data above and slightly below the observed phase change corresponded to the measured saturation pressure of the fluid. In this manner, the P-V plot confirms the saturation pressure observed visually in the PVT cell. The measured pressure and volume data are then used to compute live oil compressibility above the bubblepoínt pressure and relative oil volumes over the entire pressure range. Differential Vaporization Procedure Subsequent to the completion of the CCE experiment, another sub-sample of the test fluid is charged to the PVT apparatus and the cell contents are then mixed with the magnetic mixer to allow for phase equilibration at the reservoir temperature and pressure conditions. A differential vaporization (OV) experiment is then conducted by incrementally reducing the pressure in the PVT cell in discrete steps. In these steps, the pressure is reduced below the saturation pressure, and hence, allowing the gas phase to evolve. A typical pressure stage in a OV test is described below: · The pressure in the PVT cell is reduced to a pressure just above the bubblepoint pressure of the oil. This is the starting point of the OV test. · The pressure of the fluid is then reduced to the first pressure stage (below the bubblepoint pressure) of the OV test allowing free gas to evolve. The magnetic mixer is then used to achieve equilibration between the free gas and the pressurized liquid. · The evolved gas phase is then isobarically removed from the PVT cell into an evacuated pycnometer for gravimetric density and compositional analysis by the flash procedure (see Fluid Analysis Equipment Section) · The previous two steps are repeated until either an atmospheric pressure or a predetermined abandonment pressure is reached. Mult/~Stage Separation Test WCP Oilphase-DBR 70 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: BP Field: Well: Z210PB1 Sand: Installation: Nabors 7ES Job #: 200400299 Subsequent to the completion of the DV experiment another sub-sample of the test fluid is charged to the PVT apparatus and the cell contents are then mixed with the magnetic mixer to allow for phase equilibration at the reservoir temperature and pressure conditions. A multi-stage separation experiment is then conducted by incrementally reducing the pressure and temperature conditions in the PVT cell in discrete steps. In these steps, the pressure is reduced below the saturation pressure, and hence, allowing the gas phase to evolve. A typical pressure stage in a separation test is described below: · The pressure in the PVT cell is reduced to a pressure just above the bubblepoint pressure of the oil. This is the starting point of the separation test. The temperature of the PVT cell are then reduced to the first-stage separation test temperature and allowed the cell content to equilibrate. The pressure of the fluid is then reduced to the first pressure stage (below the bubblepoint pressure) of the separation test allowing free gas to evolve. The magnetic mixer is then used to achieve equilibration between the free gas and the pressurized liquid. Prudhoe Bay ScblumbePlep . · The evolved gas phase is then isobarically removed from the PVT cell into an evacuated pycnometer for gravimetric density and compositional analysis by the flash procedure (see Fluid Analysis Equipment Section) The previous two steps are repeated in five stages to stock tank conditions. Liquid Phase Viscosity and Density Measurements During DV Step Prior to measuring the viscosity, a suitable size piston is selected with the proper viscosity range and the electromagnetic viscometer is calibrated using a fluid with known viscosity. A portion of the live reservoir fluid used in the DV test is then transferred into a high-pressure high-temperature electromagnetic viscometer. The viscometer is initially evacuated and kept at the same temperature as that of the PVT cell. During the transfer of approximately 15 cc of live hydrocarbon liquid to the evacuated viscometer, flashing of oil takes place, and hence, the viscometer system is flushed with live oil twice to make sure a representative live oil sample is taken. Subsequent to transfer of live reservoir fluid into the viscometer, the fluid system is allowed to achieve thermal and pressure equilibration. Then, the viscosity reading is taken. Following the viscosity reading, incremental pressure reduction steps are repeated as those used in DV steps. At each pressure point, the piston was allowed to run back and forth for sufficient time to achieve pressure equilibration and allow the liberated gas to migrate vertically upwards and accumulate at the top of the carrier chamber. Experiments are also conducted independently using a PVT cell for phase equilibration. The viscosity measurements done on liquid sample transferred from the PVT cell after equilibration compares very well with the measurements done on liquid sample subjected to pressure steps within the viscometer. Stock- Tank Oil (STO) Viscosity and Density Measurements A sample of STO is taken in a known capillary tube to measure the STO viscosity at a preset temperature. The temperature bath is maintained at the preset temperature. A small sample of the liquid is also transferred into the Anton Paar DMA45 densitometer to measure the density of the liquid phase. The viscosity and density measurements are repeated for data consistency check. Asphaltene, Wax and Sulfur Content Measurements WCP Oilphase-DBR 71 Job #: 200400299 I I I I I I I I I I I I I I I I I I I Client: BP Field: Well: Z210PB1 Sand: Installation: Nabors 7ES Job #: 200400299 Asphaltene content of stock-tank oil samples is conducted using the IP-143 (French Institute of Petroleum) procedure. In this procedure, the asphaltenes are characterized as the n-heptane insoluble fractions of the crude oil. Wax content of the STO is measured using UOP (Universal Oil Product) 46-64 procedure. The sulfur content of the STO is measured using ASTM D 2494 procedure. . All other STO analysis were measured according to industrial standards. Prudhoe Bay Schlumberger SAR(P)A Analysis A spinning band distillation was carried out on the original sample to establish two fractions. The initial boiling point to 300°C fraction was then analysed using a supercritical fluid chromatographic (ASTM 5186-91) method to determine the saturates and aromatics content. The greater than 300°C fraction first subjected to a gravimetric analysis to determine the pentane insoluble content (asphaltenes). This method dissolves the fraction in an equal weight of toluene, then 40 volumes of pentane were added to precipitate the insoluble portion of the sample. The precipitate was filtered, dried and weighed. The solvent was removed from the soluble portion of the sample, which was referred to as the maltenes. The maltenes were then redissolved in pentane and were chromatographically separated into saturates, aromatics and resins (polars) fraction by elution from a column filled with activated alumina, using various solvents and solvent mixtures. The solvents were then removed from each fraction and the amount of material weighed. The data from the three methods were combined to determine the amount of each component type in the original sample. Mass balances were calculated throughout the procedure to assure accurate data. High- Temperature High Pressure Filtration Test During the filtration process, it is important that the monophasic fluid remains monophasic as it passes through the filter manifold. Hence, high pressure nitrogen is used on the back side of the filter so that the equal pressure is maintained on both sides of the filter. This procedure prevents any flashing of the fluid in the filter manifold and assures filtration of a representative fluid. WCP Oilphase-DBR 72 Job #: 200400299