The URL can be used to link to this page

Home My WebLink About203-131New Plugback Esets 7/31/2024 Well Name API Number PTD Number ESet Number Date CD2-15 PB1 50-103-20386-70-00 201-159 T39326 4-26-2002 CD2-15 PB2 50-103-20386-71-00 201-159 T39327 4-26-2002 1D-42L1 PB1 50-029-22979-70-00 205-078 T39328 8-3-2005 2N-304 PB1 50-103-20382-70-00 201-130 T39329 9-12-2001 Mitre 1 PB1 50-103-20409-70-00 202-026 T39330 7-23-2002 C-26L1 PB1 50-029-22634-70-00 203-076 T39331 9-17-2003 C-26L1 PB2 50-029-22634-71-00 203-076 T39332 9-17-2003 C-26L1 PB3 50-029-22634-72-00 203-076 T39333 9-17-2003 MPU E-32 PB1 50-029-23261-70-00 205-065 T39334 7-7-2005 S-04L1 PB1 50-029-23148-70-00 203-053 T39335 7-14-2005 S-04L1 PB2 50-029-23148-71-00 203-053 T39336 7-14-2005 MPU S-05 PB1 50-029-23100-70-00 202-137 T39337 6-2-2003 B-03 PB1 50-883-20095-70-00 198-059 T39338 11-6-2003 07-28B PB1 50-029-21770-70-00 209-037 T39339 6-29-2009 16-23A PB1 50-029-22050-70-00 201-054 T39340 6-2-2003 W-34A PB1 50-029-21867-70-00 203-058 T39341 2-6-2004 SP30-W01 PB1 50-629-23476-70-00 212-142 T39342 11-14-2012 V-207L4 PB1 50-029-23390-71-00 208-070 T39343 9-11-2008 W-215 PB1 50-029-23172-70-00 203-131 T39344 9-12-2003W-WW 215 PB1 50-029-23172-70-00 203-131 T39344 9-12-2003 Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 02/09/2024 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 02/09/2024. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through 02/09/2024. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404 Report of Sundry Operations. If you have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Supervisor Hilcorp North Slope, LLC Digitally signed by Oliver Sternicki DN: cn=Oliver Sternicki, c=US, o=Hilcorp North Slope LLC, ou=PBU, email=oliver.sternicki@hilcorp.com Date: 2024.02.09 11:15:58 -09'00' Oliver Sternicki Hilcorp North Slope LLC. Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-off Report of Sundry Operations (10-404) 02/09/2024 Well Name PTD # API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date L-293 223020 500292374900 30 8/29/2023 S-09A 214097 500292077101 2 9/19/2023 S-102A 223058 500292297201 2 9/19/2023 S-105A 219032 500292297701 10 9/19/2023 S-109 202245 500292313500 7 9/19/2023 S-110B 213198 500292303002 35 9/19/2023 S-113B 202143 500292309402 10 9/19/2023 S-115 202230 500292313000 4 9/19/2023 S-116A 213139 500292318301 4 9/19/2023 S-117 203012 500292313700 3 9/19/2023 S-118 203200 500292318800 9 9/19/2023 S-122 205081 500292326500 5 9/19/2023 S-125 207083 500292336100 2 9/19/2023 S-126 207097 500292336300 3 9/19/2023 S-134 209083 500292341300 35 9/19/2023 S-200A 217125 500292284601 7 9/19/2023 S-202 219120 500292364700 13 9/19/2023 S-210 219057 500292363000 10 9/19/2023 S-213A 204213 500292299301 4 9/19/2023 S-215 202154 500292310700 3 9/19/2023 S-216 200197 500292298900 4 9/19/2023 S-41A 210101 500292264501 3 9/19/2023 W-16A 203100 500292204501 2 9/23/2023 W-17A 205122 500292185601 3 9/23/2023 Well Name PTD #API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date W-19B 210065 500292200602 8 9/23/2023 W-21A 201111 500292192901 8 9/23/2023 W-32A 202209 500292197001 4 9/23/2023 W-201 201051 500292300700 44 9/23/2023 W-202 210133 500292343400 6 9/23/2023 W-204 206158 500292333300 3 9/23/2023 W-205 203116 500292316500 3 9/23/2023 W-207 203049 500292314500 3 9/23/2023 W-211 202075 500292308000 8 9/23/2023 W-213 207051 500292335400 3 9/23/2023 W-214 207142 500292337300 10 9/23/2023 W-215 203131 500292317200 2 9/23/2023 W-223 211006 500292344000 7 9/23/2023 Z-69 212076 500292347100 2.0 27 1.5 10/24/2023 S-128 210159 500292343600 11 12/27/2023 S-135 213202 500292350800 16 12/27/2023 V-113 202216 500292312500 24 12/31/2023 V-114A 203185 500292317801 5 12/31/2023 V-122 206147 500292332800 5 12/31/2023 V-205 206180 500292333800 2 12/31/2023 V-207 208066 500292339000 8 12/31/2023 V-214 205134 500292327500 5 12/31/2023 V-215 207041 500292335100 2 12/31/2023 V-218 207040 500292335000 5 12/31/2023 V-224 208154 500292340000 16 12/31/2023 V-225 209118 500292341900 6 12/31/2023 V-01 204090 500292321000 3 1/1/2024 V-02 204077 500292320900 5 1/1/2024 V-04 206134 500292332200 5 1/1/2024 V-102 202033 500292307000 8 1/1/2024 V-104 202142 500292310300 5 1/1/2024 V-220 208020 500292338300 4 1/1/2024 W-215 203131 500292317200 2 9/23/2023 PTD z c 5 i3 ) Loepp, Victoria T (DOA) From: Zoesch, Eric <zoeseO@BP.com> Sent: Wednesday,April 15, 2015 9:15 AM To: Loepp,Victoria T(DOA) Cc: Derrick, Laurie R Subject: RE:W-215 Patch Re-Set PTD 203-131, 314-606 Follow Up Flag: Follow up Flag Status: Flagged Excellent,thank you Victoria! Eric Zoesch ) Aurora & Polaris Field PE West Base Mgmt. Team BP Exploration Alaska Inc 907-564-4695 (0) 406-270-9837(C) From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Wednesday, April 15, 2015 9:11 AM To: Zoesch, Eric Subject: RE: W-215 Patch Re-Set A new 10-403 is not necessary. This email will suffice for the added scope to the original sundry. Submit a 10-404 when work is complete. A State witnessed MIT-IA is required after stabilized injection. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 Work (907)793-1247 Victoria Loepp a(�alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.LoepQ@alaska.gov From: Zoesch, Eric [mailto:zoeseO@BP.com] Sent:Tuesday, April 14, 2015 3:59 PM To: Loepp,Victoria T(DOA) Subject: RE: W-215 Patch Re-Set 1 I will check on the status of the 404 and let you know. To your other questions, no it has not been put on injection and yes we attempted an MIT-IA; that was our means of establishing a LLR. An MIT-IA was attempted immediately after patch set,then again two days post patch.The follow-up LDL was performed pumping down the IA as well. Enc Zoesch Aurora & Polaris Field PE West Base Mgmt. Team BP Exploration Alaska Inc. 907-564-4695 (0) 406-270-9837(C) From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Tuesday, April 14, 2015 3:47 PM To: Zoesch, Eric Subject: RE: W-215 Patch Re-Set Have you filed a 404 yet? Has the well been back on injection yet and a MIT-IA conducted? From: Zoesch, Eric [mailto:zoeseO@BP.com] Sent: Tuesday, April 14, 2015 3:43 PM To: Loepp, Victoria T(DOA) Cc: Derrick, Laurie R Subject: W-215 Patch Re-Set Hi Victoria, We obtained approval a few months ago for a double-patch tubing repair in Polaris well W-215.Since that time,the two patches have been set and the top element of the upper patch appears to have not set correctly.This was observed by a LLR of 2-3 gpm at 2,000 psi (down from "12 gpm pre-patch)and a follow-up LDL run in March.This upper seal failure, while unfortunate, is the best-case failure scenario.The plan is to stab a seal-pup-packer assembly onto the existing upper patch,effectively lengthening the patch and sealing against the patch and tubing similar to a liner-top packer. Do you require a follow-up 10-403 for this additional work?The scope&intent of the work hasn't deviated from the plan laid out in the original permit;the well simply needs an additional piece of hardware in order to reestablish integrity. Thanks, Eric Zoesch Aurora & Polaris Field PE West Base Mgmt. Team BP Exploration Alaska Inc. 907-564-4695 (0) 406-270-9837(C) 2 za 3-'31 WELL LOG TRANSMITTAL RECEIVED S ,. APR 0 9 2015 PRoACrivE DiAgNosric SERVICES, INC. AOGCC DATA LOGGED 5 i'l/2015 M.K.BENDER To: AOGCC Makana Bender 333 W. 7th Ave Suite 100 SCANNED Mk.' 0 72015 �,�� Anchorage,Alaska 99501 �5 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection[Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Analisa Steger LR2 - 1 900 Benson Blvd. Anchorage, AK 99508 gancpdc@bp.com and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage,AK 99518 Fax: (907) 245-8952 1) LeakPointTM Survey 20-Mar-15 W-215 BL/ CD 50-029-23172-00 2) Signed : / 1�4;�.ai'ioV Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE(CDMEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D\Archtves\MasterTemplateFJes\Templates\Distnbutmn\TransmtttalSheets\BP_Transmit docx Image ~ject Well History File c!er Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 03 - 13 L Well History File Identifier Organizing (done) o Two-sided 11111111111" 111111 o Rescan Needed IIIIII~IIIIIIIIIII R~AN ~ Color Items: o Greyscale Items: DIGITAL DATA ~kettes, No..;L o Other, No/Type: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: BY: c;;;;) Date: I'}-. 3/ Ds-' o Other:: BY: ~ Date ~d-' 31 OS /5/ VVl f 1111111111 II1I "III /5/ V11 P Project Proofing Scanning Preparation BY: ( ___ Maria;) I X 30 .=30 + ~ '1 :: TOTAL PAGES E 7 . I -- /:;ount does not include cover she~4 Af Date:/J-, I ~ ð~ /5/ V VI 1111111111111111111 Production Scanning Stage 1 Page Count from Scanned File: 53 (Count does include cover sheet) Page Count Matches Number in Scanni1g Preparation: ~YES ~ Date: 1:J- 13/()Ç If NO in stage 1, page(s) discrepancies were found: YES NO BY: /5/ VVlP Stage 1 BY: NO Maria Date: /5/ 11111111111111 "III Scanning is complete at this point unless rescanning is required, ReScanned 11111111111111" III BY: Maria Date: /5/ Comments about this file: Quality Checked 11111111/11I1111111 10/6/2005 Well History File Cover Page,doc S • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission **err.. db.■•■•■ • DATE: Wednesday, May 01, 2013 TO: Jim Regg \---,e P.I. Supervisor ? I ( 3' SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 1 W-215 FROM: Jeff Jones PRUDHOE BAY UN POL W-215 Petroleum Inspector SCANNED Jii 1 0 8 2013 Src: Inspector Reviewed By: P.I. Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN POL W-215 API Well Number 50-029-23172-00-00 Inspector Name: Jeff Jones Permit Number: 203-131-0 Inspection Date: 4/29/2013 Insp Num: mit.1.1130430144214 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well W-215 IT 1 .—r-W ' ype nj 1 5076 IA 513 : 2570 - 2520 2514 1 1--- 1 1 i PTD 2031310 , Type Testi SPT 1Test psil 1500 , 1 OA i 7 107 - I 100 1 95 ' I Interval4YRTST 'P/F P 'I Tubingl I _1 1584 :r 1585 1: 1582 1 1589 -1 I I Notes: 2.1 BBLS methanol pumped. 1 well inspected, no exceptions noted. - 1 Wednesday, May 01, 2013 Page 1 of 1 ~ ....~~" ~~~~~~~~ Alaska Data & Consulting Services ~ ,- r~ ,? .~."~. ~:~kaa..~ ~" ~~~'' 2525 Gambell Street, Suite 400 , ,-~ °. Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description Date 08/27/09 NO. 5336 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage,AK 99501 BL Color CD 14-12 AYTU-00048 USIT L~ 07/26/09 1 1 L2-06 ANHY-00101 PRODUCTION PROFILE C~5~ 07/23/09 1 1 03-20A AYKP-00034 CROSSFLOW CHECK ~ 07/16/09 1 1 M-06A AZCM-00034 PRODUCTION LOG j' - 07/13/09 1 1 P1-11 AYS4-00086 PRODUCTION PROFILE (p L 07/21/09 1 1 02-11A AYS4-00084 LDL ~ 07/20/09 1 1 W-212 B3SQ-00011 INJ PROFILE W/WFL ' - 07l20/09 1 1 W-215 AYKP-00036 INJ PROFILE W/RST-WFL p- 07/25/09 1 1 W-207 AYKP-00035 INJ PROFILE W/RST-WFL -(SC L 07/24/09 1 1 H-29A AYQQ-00027 RST '~ 05/19/09 1 03-28 B14B-00067 RST j- Z.{ 07/17/09 1 1 B-27A AXBD-00029 MCNL L. O6/12/09 1 1 C-15A AWJI-00038 MCNL - O6/25/09 1 1 Q-04A B1JJ-00023 MCNL ' ' 05/28/09 1 1 V-05 08AKA0024 OH MWD/LWD T 10/13/OS 1 1 07-06B AWJI-00042 MCNL 07/21/09 1 1 02-33B 09AKA0149 OH MWD/LWD EDIT L 06/03/09 1 1 14-23A 09AKA0035 OH MWD/LWD EDIT • 05/12/09 1 1 H-19B 62WY-00004 MCNL (REPLACEMENT) - L 05/07/09 1 PLEASE AC;KNOWLEDGE REGEIPT BY SIGNING AND RETURNING ONE COPY EAGFI TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 • • ~~ • MEMORANDUM To: Jim Regg ~ ~ ~~~~~ P.I. Supervisor I ~~~ FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, May 14, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC W-215 PRUDHOE BAY UN POL W-21 s Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~ Comm Well Name: PRUDHOE BAY UN POL W-215 API Well Number: 50-029-23172-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ090511160623 Permit Number: 203-131-0 Inspection Date: 5/10/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We11 w-Zls Type Inj. w TVD so~6 IA o 300o z9~o 290 P.T.D 2031310 TypeTest SPT Test psi ]soo pA ~ o ~0 6s 6s Interval 4YRTST p~F P ~ Tubing 1420 1440 1440 1440 Notes' 3.4 BBLS methanol pumped. 1 well inspected; one exception noted: the IA block valve leaked to atmosphere. The IA valve was serviced by the grease crew and stopped leaking •°~'"CS~~ ~ 'gy~'pp , i"Mi 1:/44 1 ~ r ~., '?' L ~ V ~ Thursday, May 14, 2009 Page 1 of 1 OPERABLE: W-215 (PTD #20~ 10) AOGCC MITIA for compliance ~SSED Page 1 of 3 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] 2~~ 'g~Z`~ Sent: Monday, May 11, 2009 1:39 PM To: Regg, James B(DOA); Maunder, Thomas E(DOA); GPB, GC2 Welipad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); NSU, ADW Weil Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Weils Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr Cc: Quy, Tiffany; Makarov, Egor; Hoit, Ryan P(ASRC); NSU, ADW Well Integrity Engineer Subject: OPERABLE: W-215 (PTD #2031310) AOGCC MITIA for compliance - PASSED All, / Well W-215 (PTD #2031310) is an injection weii that was shut in due to a hydrate obstruction that prevented an AOGCC witnessed compiiance MITIA. The well was cleared of the obstr ction with coi il 2008. The weli was brought online on 0~9 and ailowed to sta ilize injection rates and temperatures. The weil passed an AOGCC witnessed MITIA to 3000 psi on 05/10/09 and has been reclassified as Operable. The well will resume a 4$ month compliance testing regime for injection wells. If there are any questions piease contact me. Thank you, Taylor Wellman filling in for Anna Dube/Andrea Hughes Office: 659-5102 Pager: 659-5100 x 1154 ~~~;~"~~~~ ~~~i: ~.; 2~C~~ From: NSU, ADW Well Integrity Engineer Sent: Monday, April 20, 2009 7:24 PM To: NSU, ADW Well Integrity Engineer; 'Regg, ~ames B(DOA)'; 'Maunder, Thomas E(DOA)'; GPB, GC2 Welipad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr Cc: Winslow, )ack L.; Makarov, Egor Subject: UNDER EVAL: W-215 (PTD #2031310) To place on injection and obtain AOGCC MITIA for compliance Hi all, Through the use of a coii tubing intervention well W-215 (PTD #2031310) has recently been cleared of a hydrate obstruction in the tubing that previously prevented it from being placed on injection for an AOGCC witnessed MITIA. The well is again being ciassified as Under Evaluation so that it may be piaced on injection and an AOGCC witnessed MITIA can be obtained for UIC compliance. Please place the well on injection watching for an increase in IA pressure as the well reaches temperature. Well Integrity will schedule an AOGCC witnessed MITIA once the well has stabilized. The plan forward for the well is as foliows: 1. Operations: Place well on injection 2. Fullbore: AOGCC MITIA Please call with any questions. Thank you, 8/7/2009 OPERABLE: W-215 (PTD #20~ 10) AOGCC MITIA for compliance ~SSED Page 2 of 3 ,~ason E. ~DahlemforAnna ~ude/Andrea ~'ugFies alternate - Taylor Wellman bp Alaska - Well Integrity Engineer office: 907-659-5098 cell: 713-299-2651 pager: 659-5100 x1446 harmony: 758-2418 From: NSU, ADW Well Integrity Engineer Sent: Thursday, November 13, 2008 7:11 PM To: 'Regg, James B(DOA)'; 'Maunder, Thomas E(DOA)'; GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr Cc: Holt, Ryan P(ASRC); Makarov, Egor; NSU, ADW Well Integrity Engineer Subject: NOT OPERABLE: W-215 (PTD #2031310) Hydrates in Tubing All, Well W-215 (PTD #2031310) currently has hydrates in the tubing as tagged at 9870' slickline MD. The well cannot be placed on injection until the tubing is thawed. An attempt to pump down the tubing was made on 11/06/08 to no avail. The well will require coiled tubing work. Until the hydrate ciean out is complete, the well has been reclassified as Not Operable. Once the tubing is clear, the well wiil then be reclassified to be put on injection for the AOGCC witnessed MIT-IA. Please call with any questions or concerns. Thank you, Andrea Hughes From: NSU, ADW Well Integrity Engineer Sent: Thursday, October 23, 2008 7:45 PM To: 'Regg, James B(DOA)'; 'Maunder, Thomas E(DOA)'; GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimizatiqn Engr Cc: Holt, Ryan P(ASRC); Makarov, Egor; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: W-215 (PTD #2031310) To place on injection and obtain AOGCC MITIA for compliance Hi all, Well W-215 (PTD #2031310) has been reclassified as Under Evaluation so that it may be placed on injection and an AOGCC witnessed MITIA can be obtained for UIC compliance. Please place the well on injection watching for an increase in IA pressure as the weil reaches temperature. Well Integrity will schedule an AOGCC witnessed MITIA once the well has stabilized. The plan forward for the weli is as follows: 1. Operations: Place well on injection 2. Fullbore: AOGCC MITIA 8/7/2009 OPERABLE: W-215 (PTD #20~10) AOGCC MITIA for compliance ~ASSED Page 3 of 3 Please call with any questions. Thank you, Anna ~ude, 2~. E. Well Integrity Caardinator GPB Wells Group Phone: (907) 659-5102 Pager: (907} 659-5100 x1154 8/7/2009 LTNDER EVAL: W-215 (PTD #~31310) To place on injection and obta~OGCC MITI... Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Monday, April 20, 2009 7:24 PM ~~?-~~ ~~6 ~~c~ To: NSU, ADW Well Integrity Engineer; Regg, James B(DOA); Maunder, Thomas E(DOA); GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr Cc: Winslow, Jack L.; Makarov, Egor Subject: UNDER EVAL: W-215 (PTD #2031310) To place on injection and obtain AOGCC MITIA for compliance Hi all, Through the use of a coil tubing intervention well W-215 (PTD #2031310) has recently been cleared of a hvdrate obstruction in the tubing that previously prevented it from being placed on injection for an AOGCC witnessed MITIA. The weil is again being classified as Under Evaluation so that it may be placed on injection and an AOGCC witnessed MITIA can be obtained for UIC compliance. Please place the well on injection watching for an increase in IA pressure as the well reaches temperature. Well Integrity will schedule an AOGCC witnessed MITIA once the well has stabilized. f~/ V The plan forward for the well is as follows: ~~C ~~.~.,te~:-~ 1. Operations: Place well on injection 2. Fullbore: AOGCC MITIA P~'S`'~~ ~"~"~ ~1~~~~ Please call with any questions. Thank you, ,~ason ~. ~DahCem forAnna ~u6e/And'rea ~fughes alternate - Taylor Wellman bp Alaska - Weil Integrity Engineer office: 907-659-5098 cell: 713-299-2651 pager: 659-5100 x1446 harmony: 758-2418 * : ~,~,~, ~ r , +`, tr r ~t. 4~ ._ v .-~. ~ l..l~: ;. From: NSU, ADW Well Integrity Engineer Sent: Thursday, November 13, 2008 7:11 PM To: 'Regg, James B(DOA)'; 'Maunder, Thomas E(DOA)'; GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr Cc: Holt, Ryan P(ASRC); Makarov, Egor; NSU, ADW Well Integrity Engineer Subject: NOT OPERABLE: W-215 (PTD #2031310) Hydrates in Tubing All, Well W-215 (PTD #2031310) currently has hydrates in the tubing as tagged at 1870' siickline MD. The well cannot be placed on injection until the tubing is thawed. An attempt to pump down the tubing was made on 11/06/08 to no avail. The well will require coiled tubing work. Until the hydrate clean out is complete, the well has 8/6/2009 UNDER EVAL: W-215 (PTD #~31310) To place on injection and obt~OGCC MITI... Page 2 of 2 been reclassified as Not Operable. Once the tubing is clear, the weil will then be reclassified to be put on injection for the AOGCC witnessed MIT-IA. Please call with any questions or concerns. Thank you, Andrea Hughes From: NSU, ADW Well Integrity Engineer Sent: Thursday, October 23, 2008 7:45 PM To: 'Regg, James B(DOA)'; 'Maunder, Thomas E(DOA)'; GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr Cc: Holt, Ryan P(ASRC); Makarov, Egor; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: W-215 (PTD #2031310) To place on injection and obtain AOGCC MITIA for compliance Hi all, Well W-215 (PTD #2031310) has been reclassified as Under Evaluation so that it may be placed on injection and an AOGCC witnessed MITIA can be obtained for UIC compliance. Please place the well on injection watching for an increase in IA pressure as the well reaches temperature. Well Integrity will schedule an AOGCC witnessed MITIA once the well has stabilized. The plan forward for the weil is as foilows: 1. Operations: Place weil on injection 2. Fullbore: AOGCC MITIA Please call with any questions. Thank you, Anna ~Du6e, ~P. E. Well Integrity Caordinatar GPB Wells Group Phone: (907) 659-5102 Pager: (907} 659-5100 x1'154 8/6/2009 NOT OPERABLE: W-215 (PTD #2031310) Hydrates in Tubing Page 1~2~ f31atl~-- Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.comj Sent: Thursday, November 13, 2008 7:11 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr Cc: Holt, Ryan P (ASRC); Makarov, Egor; NSU, ADW Well Integrity Engineer Subject: NOT OPERABLE: W-215 (PTD #2031310) Hydrates in Tubing Ali, Well W-215 {PTD #2031310) currently has hydrates in the tubing as tagged at 1870' slickline MD. The well cannot be placed an injection until the tubing is thawed. An attempt to pump down the tubing was made on 11f06/08 to no avail. The well will require coifed tubing work. Untii the hydrate clean out is complete, the Weil has been reclassified as Not Operable. Once the tubing is clear, the well will then be reclassified #o be put on injection for the AOGCC witnessed MIT- IA. Please call with any questions or concerns. Thank you, Andrea Hughes From: NSU, ADW Well Integrity Engineer Sent: Thursday, October 23, 2008 7:45 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr Cc: Holt, Ryan P (ASRC); Makarov, Egor; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: W-215 (PTD #2031310) To place on injection and obtain AOGCC MITIA for compliance Hi all, Well W-215 (PTD #2031310) has been reclassified as Under Evaluation so that it may be placed on infection and an AOGCC witnessed MITIA can be obtained for UIC compliance. Please place the well on injection watching for an increase in IA pressure as the well reaches temperature. Well Integrity will schedule an AOGCC witnessed MITIA once the well has stabilized. The plan forward for the well is as follows: 1. Operations: Place welt on injection 2. Fullbore: AOGCC MITIA Please call with any questions. Thank you, Anna ~u6e, ~'. E. Well Integrity Coordinator GF8 Wells Group ll128/2008 • • -~. MICROFILMED 03/01/2008 DO NOT PLACE ~`_ ._;,. ~:: ;~, ~~- ,F ~. ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_InsertsiMicrofilm Marker.doc . Page 1 of2 . Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, August 16, 2007 11 :29 AM To: 'Preble, Gary B (SAIC)' Cc: 'Stephen F Davies'; 'Robert J Fleckenstein'; Harry Engel; 'Arthur C Saltmarsh' Subject: RE: PBU W-215 (203-131) Gary, Further to the 404 for this well. I have spoken with Commissioner Foerster on this matter. As noted the 404 reporting conversion is very delinquent. Another item is that the date you entered at the bottom is the conversion date and not the date that the form was prepared and signed. The proper date at the bottom of the form should be the date prepared and signed. You do not need to resubmit the form per Commissioner Foerster. Presently, there isn't a dedicated block on the form where you can list the conversion date, although internally we may look into this. Until then, the conversion date could be included at the top left where Convert to WAG is entered. If there is more work than simply changing from water to MI, an operations report would be attached and there would be a work complete date. In cases similar to yours, I believe that CPAI includes a one line operations summary that gives a date and the comment "Convert to WAG". Your choice. Call or message with any questions. Tom Maunder, PE AOGCC -~--~._..- ~-----"-----------~--_._--------_._~---..,....---_. From: Maunder, Thomas E (DOA) Sent: Thursday, August 16, 2007 10:09 AM To: 'Preble, Gary B (SAlC)' Subject: RE: PBU W-215 (203-131) 5CANNED AU G 1 6lDD7 Gary, Based on the date when MI was started, this 404 is very delinquent. When fluids are changed in a well, the 404 should be submitted within 30 days. You might also take a look at W-209 and S-215. They were also authorized for MI in AIO 25A. Tom Maunder, PE AOGCC ---~~-~-- ----~--~-,--,------~ From: Preble, Gary B (SAIC) [mailto:Gary.Preble@bp.com] Sent: Thursday, August 16, 2007 9:46 AM To: Maunder, Thomas E (DOA) Subject: RE: PBU C-36A (200-002) and PBU W-215 (203-131)--again Tom, W-215 was placed in WAG on 1/7/06 Gary Preble Petroleum Data Management Engineer SAIC 907-564-4944 preblegb@bp.com ~'·_·_______________~.M_~____.,~__,_""____~_____"___ From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, August 15,20071:02 PM To: Preble, Gary B (SAlC) 8/16/2007 . Page 2 of2 . Cc: Arthur C Saltmarsh; Stephen F Davies Subject: RE: PBU C-36A (200-002) and PBU W-215 (203-131)--again Gary, On W-215 would you please provide the date that the well was placed in WAG service? Email is fine. Tom Maunder, PE AOGCC ~-~_._~_.__._-<--,--_.---~- --~.~----~------ ~-<----- From: Maunder, Thomas E (DDA) Sent: Wednesday, August 15, 2007 12: 11 PM To: 'Preble, Gary B (SAlC)' Cc: 'Arthur C Saltmarsh'; 'Stephen F Davies' Subject: PBU C-36A (200-002) and PBU W-215 (203-131) Gary, On these 404s the measured and tv depths for the perforations are mixed. These are the only items I have identified with these documents. It is not necessary to resubmit the 404s I have made hand corrections. Call or message with any questions. Tom Maunder, PE AOGCC 8/16/2007 · STATE OF ALASKA .. ALASKA OIL AND GAS CONSERVATION COM"ION Comm¡s~1=PORT OF SUNDRY WELL OPERATIONS D D D "Lt_ ·'iIf ".. G 0 ~~ 200/ é~~ ffl] 1. Operations A:. andon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Ope rat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development Stratigraphic P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (It): 3. Address: 80.8 KB 8. Property Designation: ADLO-047451 11. Present Well Condition Summary: Total Depth measured 10594 ' feet true vertical 5604.22 - feet Effective Depth measured 10495 ' feet true vertical 5548.54 - feet Casing Length Size MD Conductor 80 20" 94# H-40 28 - 1 08 Surface 4306 9-5/8" 40# L-80 28 - 4334 Production 10554 7" 26# L -80 26 - 10580 '()\CoCo Perforation depth: Measured depth..:. 9825 -~ tft?f'f-=- ~\~~ . True Vertical depth: 1~ - 5367 Q.( / -=- "" \/ ~ ~ß-d~ "5 Stimulate D Other 0 Convert to WAG Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 203-1310 Exploratory Service w 6. API Number: 50-029-23172-00-00 9. Well Name and Number: W-215 10. Field/Pool(s): Prudhoe Bay Field/ Polaris Pool Plugs (measured) None Junk (measured) None TVD 28 - 108 28 - 2689.17 26 - 5596.35 Burst 1530 5750 7240 Collapse 520 3090 5410 - 4-1/2" 12.6# L-80 3-1/2" 9.2# L-80 4-1/2" Baker PRM Packer 3-1/2" Baker PremierTCII Packer 4-1/2" Baker S-3 Perm Packer o 24 - 9640 9638 - 10075 9630 9875 10034 o Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: <.o"'\\>\~\~ G.S \ ~~~ q (:) ~ - 0 s j.çt11V\ I\P- ~II S -<.:) "'\ Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations OiI-Bbl o o Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure o 383 0 o 1780 0 Tubing pressure 1282 2617 15. Well Class alter oroposed work: Exploratory Development 16. Well Status atter proposed work: Oil Gas WAG W 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 13. Contact Gary Preble Service WINJ WDSPL Sundry Number or N/A if C.O. Exempt: N/A V Title Data Management Engineer Date 1 m2006 Signature Phone 564-4944 AUG 1 6 20D7 ORIGINAL RBDMS Submit Original Only À:S~J; DATA SUBMITTAL COMPLIANCE REPORT 12/5/2005 API ¿~!29~~2~O~ Operator BP EXPLORATION (ALASKA) INC Well Name/No. PRUDHOE BAY UN POL W-215 Permit to Drill 2031310 (l!iC Y ~ "-"-"--';;;'--- 5604 , Current Status 1WINJ Completion Status 1WINJ Completion Date 9/23/2003 10594 /" TVD MD -------_._----- -~-.__.._-- -----.---- -- ~ -- ~ -~~- REQUIRED INFORMATION Directional surv~ ~ Samples No Mud Log No DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, DEN, NEU, PWD, USIT Well Log Information: (data taken from Logs Portion of Master Well Data Maint . Electr Dataset Number Name 12743 Gamma Ray Directional Survey Directional Survey Logl Data Digital Type Med/Frmt ;,¡¡:o-- C Pds (¡Ii!; 0 Jitf1' D Interval Start Stop 101 1373 o 1 0594 o 1372 Log Log Scale Media OH/ CH Received Comments Open 9/27/2004 MWD, MD, TVD, GR 11>1 10/24/2003 Schlumberger & Anadrill 10/24/2003 Schlumberger & Anadrill - PB1 Run No 1 ()~..,bS 6.V\,t.. '\ 1~Jo2'O05 Sdnunlut;:O,yer & AlldJlill 10/24/2003 Schlumberger & Anadrill 10/24/2003 Schlumberger & Anadrill - PB1 Case 5/3/2004 INJECTION PROFILE W/ WARM BACK SURVEY/PFCSITTG/PI LS/ PBMS MWD, MD, GR, PB1 MWD, TVD, GR, PB1 LDWG, MWD, MD & TVD, VISION RESISTIVITY LDWG, MWD, MD ,VISION RESISTIVITY, GR LDWG, MWD,TVD ,VISION RESISTIVITY, GR LDWG, PDC GAMMA RAY LDWG, PDC GAMMA RAY, ULTRA SONIC BOND LOG, USITITEMP/GR/CCL o 1n<;ciM o 1 0594 o 1372 O;I'C'vl;VIIc::t; t)I,.UVV)" F~ ,., ~ ~ Directional Survey Directional Survey 9490 10346 5 Blu Injection Profile ~ A1743 Gamma Ray ~ 643 Gamma Ray E~Pds ~duction/Resistivity ~g ~4 I nd uction/Resistivity (till) t.rõg 4744 I nd uction/Resistivity "'t V ,~ Ev-G Pds ~46 Cement Evaluation ~ ,;1"2746 Cement Evaluation 108 1318 Open 9/27/2004 108 1318 Open 9/27/2004 101 10599 Open 9/27/2004 101 10590 Open 9/27/2004 101 10590 Open 9/27/2004 8179 10438 Case 9/27/2004 8179 10438 Case 9/27/2004 Blu Blu . 25 Blu 25 Blu Blu Permit to Drill 2031310 DATA SUBMITTAL COMPLIANCE REPORT 12/5/2005 Well Name/No. PRUDHOE BAY UN POL W-215 Operator BP EXPLORATION (ALASKA) INC MD 10594 TVD 5604 Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y~ Chips Received? """'7ì"'H--- Analysis Received? ....,..,..,.,-- Comments: Compliance Reviewed By: Completion Date 9/23/2003 ~ Completion Status 1WINJ Interval Start Stop Sent Received Daily History Received? Formation Tops Current Status 1WINJ Sample Set Number Comments Q/N G/N Date: API No. 50-029-23172-00-00 UIC Y 8 ~~r-- . . c¡ (2- 7 Schlumbel'gel' Schlumberger-DCS 2525 Gambell S~ Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well ~f) ~ -1'ì~-114A "{)l{:- 11'- 2,213 ,.. V-213 -211 ~ If-o 2. Ii /~~;115 ,¡" W-215 203 -f~ , W-215 ~J"13(/ W-215 PB1 Job# Log Description 10662970 SCMT 10877764 USIT 10877764 CH EDIT PDC-GR (US IT) 10679059 US IT 10679059 CH EDiT PDC-GR (USiT) 10662954 USiT 10662954 CH EDIT PDC-GR (USIT) 40009586 OH EDIT MWD DATA 40009586 OH EDIT MWD, GR DATA 11/17/03 07/25/04 07/25/04 03112/04 03/12/04 09/20/03 09120/03 09109-16/03 09/09-10/03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc, Petrotechnical Data Center LR2-1 900 E Benson Blvd, Anchorage AK 99508-4254 Date Delivered: 9f7/o{ 09/27/04 NO. 3219 Company: Alaska Oil & Gas Cons Comm "Attn. rtbUIII ....ed:t.ulI- 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Orion Polaris Color CD Date BL . . . STATE OF ALASKA _ ALASKA AND GAS CONSERVATION COM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25,105 20AAC 25.110 o GINJ a WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 4313' NSL, 1186' WEL, SEC. 21, T11 N, R12E, UM Top of Productive Horizon: 1577' NSL, 908' EWL, SEC. 14, T11N, R12E, UM Total Depth: 1766' NSL, 1530' EWL, SEC. 14, T11N, R12E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 612049 y- 5959291 Zone- ASP4 TPI: x- 619378 y- 5961947 Zone- ASP4 Total Depth: x- 619997 y- 5962146 Zone- ASP4 18. Directional Survey a Yes 0 No 21. Logs Run: MWD, GR, RES, DEN, NEU, PWD, US IT 22. One Other 5. Date Comp., Susp., or Aband. 9/23/2003 6. Date Spudded 9/10/2003 7. Date T.D. Reached 9/16/2003 8. Elevation in feet (indicate KB, DF, etc.) KBE = 80.8' 9. Plug Back Depth (MD+ TVD) 10495 + 5549 Ft 10. Total Depth (MD+TVD) 10594 + 5604 Ft 11. Depth where SSSV set (Nipple) 3906' MD 19. Water depth, if offshore N/A MSL CASING, LINER AND CEMENTING RECORD 20" x 34" 9-5/8" 215.5# 40# 26# A53 L-80 L-80 Surface 28' 26' 7" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 4-1/2" Gun Diameter, 5spf MD TVD MD TVD 9825' - 9855' 5183' - 5199' 9972' - 10012' 5262' - 5283' 10096' - 10166' 5329' - 5367' 26. Date First Production: Revised: 12/04103, Put on Inj. & Add Peri 1 b. Well Class: o Development 0 Exploratory o Stratigraphic a Service 12. Permit Number 203-131 13. API Number 50- 029-23172-00-00 14. Well Number PBU W-215i 15. Field and Pool Prudhoe Bay Field / Polaris Pool 16. Lease Designation and Serial No. ADL 047451 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) 108' 4334' 10580' 48" 260 sx Arctic Set (Approx.) 12-1/4" 725 sx AS Lite III, 417 sx Class 'G' 8-3/4" 432 sx Class 'G' 24. SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2", 12.6#, L-80 9638' 9630' 3-1/2",9.2#, L-80 9638' - 10075' 9875' & 10034' AClo;FRÁcfûRE,·CEMENfSóUEEzE;Efc. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 105 Bbls of Diesel November 18, 2003 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Water Injection Oll-BBl GAs-McF CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (atta~h s~para~ ~t¡ee~ if necessary). Submit core chips; if none, state "none". UEl.. - 4 ZUOj DEe ~ Wû:\ PRODUCTION FOR TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ...... Press. 24-HoUR RATE-," Oll-BBl 27. None ... BfL Form 10-407 Revised 2/2003 W ATER-BBl GAs-McF WATER-BBl ORIGINAL CONTINUED ON REVERSE SIDE CHOKE SIZE I GAs-all RATIO all GRAVITY-API (CORR) RECEIVED Alaska Oil & Gas Cons. Commission Anchorage / '-0V 2ß. GEOLOGIC MARKERS. NAME MD TVD Ugnu 6157' 3508' Ugnu M Sandstones 8814' 4691' Schrader Bluff N Sandstones 9409' 4960' Schrader Bluff 0 Sandstones 9715' 5123' OBa 9817 5178' OBb 9874' 5209' OBc 9972' 5262' OBd 10090 5325' OBe 10225' 5399' OBf 10302' 5441' Base Schrader I Top Colville 10401' 5496' 30. List of Attachments: Summary of Daily Drilling Reports, Surveys aMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 29. None RECEIVED DEC - 4 2003 Alaska Oil & Gas Cons. Commission Anchorage Title 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed 4n^ .. .... W 1lQ.#" Terrie Hubble -- IWu ~. \VXi'J'-t 203-131 Date l~..Otf..Q3 Technical Assistant Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. PBU W-215i Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble. 564-4628 Michael Triolo. 564-5774 ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 o.!q. "¡,, , GI ."-' ~ . . Well: Field: API: Permit: Date W-215 Prudhoe Bay Unit 50-029-23172-00 203-131 Accept: Spud: Release: Rig: 09/09/03 09/1 0/03 09/23/03 Nabors 9ES POST RIG WORK 09/22/03 DRIFT TBG W/2.75 LIB TO BALL & ROD. 11/13/03 PULL BALL & ROD. PULL DEK & SET DGLV IN STA #5. MIT-T AND TEST PACKER TO 2100 PSI- PASSED. PULL RHC. ATTEMPT TO SET SWS FIRING HEAD, SAT DOWN IN STA #2 @ 9925 SLM. 11/14/03 FISH FIRING HEAD FROM GLM #2. SET FIRING HEAD. FIRED GUNS. PERF 10096' -10166'. RUN 2.62 LIB OUT TT SET DOWN @ 10,365'SLM. RUN SBHPS (SEE PETRADAT REPORT FOR PRESSURES). PUMP TRUCK RIGGING UP INJECTION TEST. 11/15/03 T /1/0= 0/100/150. INJECTIVITY TEST = 5.1 BPM @ 2150 PSI. PUMPED 40 BBLS OF 50/50 MEOH, 270 BBLS OF SEAWATER DOWN THE TUBING. PUMPED 40 BBLS OF 50/50 TO FP THE TBG. STANDBY WHILE SLlCKLlNE PULLED VALVES. PUMP 24 BBLS OF 50/50 AS INSTRUCTED BY HES. PUMP 13 BBLS OF 50/50 TO HELP HES GET DOWN HOLE. RDMO. FINAL T/I/O= 250/250/50. DISPLACE TUBING W/SEA WATER - FREEZE PROTECT W/METH 50/50. SET X-CATCHER. PULL DGLV'S FROM STA #1 & #3. SET RKFS IN STA #1 & #3. PULL CATCHER SUB. FISH LEFT IN HOLE: 90' PERF GUN, 5' FIRING HEAD & 5' OF 1.5" STEM W/ 13/8" FN, FISH TAGGED @ 10,365'SLM. TURN WELL OVER TO DSO. 11/22/03 T/I/O = 1100/520/170. TEMP = HOT. MIT -IA TO 1840 PSI PASSED. (AOGCC STATE WITNESS, CHUCK SCHEEVE). PRESSURED IA TO 1840 PSI WITH 3 BBLS OF NEAT METHANOL. STARTED 30 MIN TEST. IA LOST 20 PSI IN THE 1ST 15 MIN AND 0 PSI IN THE 2ND 15 MIN. BLED IA TO 150 PSI. FINAL WHP'S = 1100/150/200. 11/23/03 T/I/0=1930/220/190, TEMP=118. MONITOR WHP'S (POST MITIA). . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us ~~ !) \-¿~03 OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay I PBU I W-215 11/22/03 Mellveson Chuck Scheeve W, ~elllw-2", W,-21, 5""",,), "Type Inj. Is ~....,·t~ype test P Notes: Initial AOGCC witnessed MITIA. Packer Depth TVD I 5,076' TUbingl Test psi 1500 Casing Pretest 11001 520 Initial 15 Min, 30 Min. 11001 11001 1100llnterval 1820 1800 1800 P/F I P weill I Type Inj. I I TVD I I TUbing II nterval P.T.D. Type test Test psi Casing P/F Notes: weill Type Inj'l I TVD I I TUb~ngl I Interval I P.T.D. Type test Test psi Casing P/F Notes: weill Type Inj'l I TVD I I TUbing II ntervall P.T.D. Type test Test psi Casing P/F Notes: weill Type Inj'l I TVD I I TUb~ngl Intervall P.T.D. Type test Test psi Casing P/F Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting MIT Report Form Revised: 06/19/02 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test MIT PBU W-21511-22-03.xls INTERVAL Codes I = Initial Test 4= Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) . . &:6-/3/ MWDILWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No W-215i Date Dispatched: 9-Sep-03 Installation/Rig Nabors 9ES Dispatched By: Nate Rose Data No Of Prints No of Floppies Surveys 2 OCT 24 " Received By:~L~-'"~ ,-C Please sign and return to: James H. Johnson ~ BP Exploration (Alaska) Inc. Petrotechnical Data Center (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907-564-4005 e-mail address:johnsojh@bp.com LWD Log Delivery V1.1 , Dee '97 ~~~\\\~ . . f) 03'- /31 MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No W-215i PB1 Date Dispatched: 9-Sep-03 Installation/Rig Nabors 9ES Dispatched By: Nate Rose Data No Of Prints No of Floppies Surveys 2 PlED : "t (~ ~r í~ /1· oJ 'Iif ~ CG'mmiss!on , C Received By: ~~,,'\..U~~\/"\. Please sign and return to: James H. Johnson BP Exploration (Alaska) Inc. Petrotechnical Data Center (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax:90Y·564-4005 e-mail address:johnsojh@bp.com LWD Log Delivery V1.1, Dee '97 ~, ~~, . c-· \"- ~h fY\ ~ . STATE OF ALASKA ,__ ALASKA AND GAS CONSERVATION COMI\fWION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25,110 o GINJ IBI WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 4313' NSL, 1186' WEL, SEC. 21, T11N, R12E, UM Top of Productive Horizon: 1577' NSL, 908' EWL, SEC. 14, T11N, R12E, UM Total Depth: 1766' NSL, 1530' EWL, SEC. 14, T11N, R12E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 612049 y- 5959291 Zone- ASP4 TPI: x- 619378 y- 5961947 Zone- ASP4 Total Depth: x- 619997 y- 5962146 Zone- ASP4 18. Directional Survey IBI Yes 0 No 21. Logs Run: MWD, GR, RES, DEN, NEU, PWD, USIT One Other 5. Date Comp., Susp., or Aband. 9/23/2003 6. Date Spudded 9/10/2003 7. Date T.D. Reached 9/16/2003 8. Elevation in feet (indicate KB, DF, etc.) KBE = 80.8' 9. Plug Back Depth (MD+ TVD) 10495 + 5549 Ft 10. Total Depth (MD+TVD) 10594 + 5604 Ft 11. Depth where SSSV set (Nipple) 3906' MD 19. Water depth, if offshore NIA MSL 22. CASING SIZE 20" x 34" 9-5/8" 7" GRADE A53 L-80 L-80 CASING, liNER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 108' 48" 28' 4334' 12-1/4" 26' 10580' 8-3/4" CEMENTING RECORD 260 sx Arctic Set (Approx.) 725 sx AS Lite III, 417 sx Class 'G' 432 sx Class 'G' WT.PER FT. 215.5# 40# 26# 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 4-112" Gun Diameter, 5 spf MD TVD MD TVD 9825' - 9855' 5183' - 5199' 9972' - 10012' 5262' - 5283' 26. Date First Production: Not on Injection Yet Date of Test Hours Tested PRODUCTION FOR TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED ........ Press. 24-HoUR RATE"'?" 24. SIZE 4-1/2", 12.6#, L-80 3-1/2", 9.2#, L-80 25. 1 b. Well Class: o Development 0 Exploratory o Stratigraphic IBI Service 12. Permit Number 203-131 13. API Number 50- 029-23172-00-00 14. Well Number PBU W-215i 15. Field and Pool Prudhoe Bay Field 1 Polaris Pool 16. Lease Designation and Serial No. ADL 047451 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) AMOUNT PUllED TUBING RECORD DEPTH SET (MD) 9638' 9638' - 10075' PACKER SET (MD) 9630' 9875' & 10034' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 105 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Water Injection Oil-Bel GAs-McF WATER-Bel 27. Brief description of lithology, porosity, fractures, apparent~~;: ~~T~resence of oil, gas or water (att~~~LVJf:Jl~cessary). Submit core chips; if none, state "none". rECi:'¡ê.'1:', ," ; None : ,/~~£~. ~ VE!ilf! ED '. ~<.._~ 1., -. ~"'! '"",''''-) .:..... "",:\ Oil-Bel GAs-McF WATER-Bel OC1 2; '"7 2ü03 R9DMS BfL ORfGfNAL Form 10-407 Revised 2/2003 CONTINUED ON REVERSE SIDE CHOKE SIZE I GAS-Oil RATIO Oil GRAVITY-API (CORR) 23 " .< ,., ~)v' 28. GEOLOGIC MARKERS .. 29. ~ JRMATION 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 6157' Ugnu M Sandstones 8814' Schrader Bluff N Sandstones 9409' Schrader Bluff 0 Sandstones 9715' OBa 9817 OBb 9874' OBc 9972' OBd 10090 OBe 10225' OBf 10302' Base Schrader I Top Colville 10401' 3508' None 4691' 4960' 5123' 5178' 5209' 5262' 5325' 5399' 5441' 5496' 30. List of Attachments: Summary of Daily Drilling Reports, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~. HüM&- Title Technical Assistant Date (O(d::3/a...~ PBU W -215i 203-131 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Michael Triolo, 564-5774 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 u¡\¡ûl¡\~AL BP Page 1 of 1 Leak-Off Test Summary Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) EMW 4,334.0 (ft) 2.693.0 (ft) 9.00 (ppg) 380 (psi 1,639 (psi 11.72 (ppg) . . Printed: 9/29/2003 9:14:00 AM Legal Name: W-215i Common Name: W-215i Test Date Test Type 9/15/2003 LOT . . Page 1 of 9 BP . . Operations Summary Report.. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-215i' W-215i DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Date From - To Hours Task Code NPT. Phase 9/9/2003 1.00 MOB 4.00 MOB P P PRE PRE 12:00 - 13:00 13:00 - 17:00 17:00-21:00 4.00 DIVRTR P SURF 21 :00 - 22:00 1.00 DIVRTR P SURF 22:00 - 00:00 2.00 DRILL P SURF 9/10/2003 00:00 - 01 :00 1.00 DRILL P SURF 01 :00 - 01 :30 0.50 DRILL P SURF 01 :30 - 04:00 2.50 DRILL P SURF 04:00 - 05:00 1.00 DRILL P SURF 05:00 - 14:00 9.00 DRILL P SURF 14:00 - 15:00 1,00 DRILL P SURF 15:00 -17:00 2.00 DRILL P SURF 17:00 - 18:00 1.00 DRILL P SURF 18:00 - 21 :00 3.00 DRILL P SURF 21 :00 - 00:00 3.00 DRILL N DPRB SURF 9/11/2003 00:00 - 01 :00 1,00 DRILL N DPRB SURF 01 :00 - 23:30 22.50 DRILL P SURF 23:30 - 00:00 0.50 DRILL P SURF 9/12/2003 0.50 DRILL P SURF 00:00 - 00:30 " Start: Rig Release: Rig Number: 9/9/2003 9/23/2003 Spud Date: 9/10/2003 End: 9/23/2003 Descriptionof Operations Move shop, camp and pits Move rig off of W-205 and spot over W-215. RU surface equipment and diverter line. Spot pits. Take on water and mix spud mud Rig accepted @ 16:00 NU riser and diverter. Function test diverter system. Witness of diverter test waived by Lou Grimaldi with AOGCC. PU BHA #1. MU jar stand. MU BHA #1 MU collars, stand back in derrick. PU BHA #1, MU Bit. Pre-Spud meeting RIH and tag bottom of 20" conductor at 108'. Drill from 108' to 352'.650 gpm, 850 psi. Circ hole clean, POH 2 stands of HWDP. PU jar stand. Wash to bottom with HWDP, Directional drill from 352' to 1372'. 650 gpm, 1620 psi, 0-50 rpm. 73 klbs up, 68 klbs down, 70 klbs rotate. 3.8 klbs torque, 20 klbs WOB. Sliding to build angle. 30' wipe on connections at 650 gpm and 50 rpm, reducing pump rate on the down stroke. Circulate hole clean at 675 gpm and 1800 psi POH for bit, unable to build angle as per plan and decreased PR. PU new HTC 12-1/4" MX-C1 bit. RIH to 418'. tag obstrution at 418', Kelly up and pump 150 gpm and 30 rpm, Continue RIH pumping and rotating as required to push obstruction down to 1009'. At 1009' worked pipe for 55 minutes at 150 gpm and 25 rpm, unable to work by or push obstruction down. Sidetrack hole at 1009'. Directional drill from 1009' to 1200'. 650 gpm, 1820 psi, 0-50 rpm. 77 klbs up, 69 klbs down, 74 klbs rotate. 5.8 klbs torque, 30-35 klbs WOB. Sliding to build angle. 30' wipe on connections at 650 gpm and 50 rpm, reducing pump rate on the down stroke. AST last 24 hrs. = 7,51 hrs. ART last 24 hrs. = 2.10 hrs. Total Drilling Time = 9.61 hrs. Directional drill from 1200' to 1372'. 650 gpm, 1820 psi, 0-50 rpm. 77 klbs up, 62 klbs down, 72 klbs rotate. 5.3 klbs torque, 30-35 klbs WOB. Sliding to build angle. 30' wipe on connections at 650 gpm, reducing pump rate on the down stroke. Directional drill from 1372' to 4344'.620 gpm, 3500 psi, 0-50 rpm. 106 klbs up, 61 klbs down, 71 klbs rotate. 8-9 klbs torque, 30-35 klbs WOB. Sliding -20' on every third stand to maintain angle at 63 degrees. Drill using "Blow and Go" practices, 30' wipe on connections at drilling flow rate and no rotation. Circulate 15 bbllow vis sweep surface to surface. Reciprocate while pumping 650 gpm at 2800 psi and 100 rpm. Continue circulating lo-vis sweep surface to surface. Circulate and condition hole for wiper trip. 650 gpm @ 3240 psi. Printed: 9/2912003 9:14:13AM . . Page 2 of9 BP 'Ope,rations S",mmary Report ',' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-215i' W-215i DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Date From - To Hours Task Code NPT Phase _._-_.._.~.-.--_...----..__.__...,_._._---_._----_._.-.. 9/12/2003 00:00 - 00:30 0.50 DRILL P SURF 00:30 - 01 :00 0.50 DRILL P SURF 01 :00 - 01 :30 0.50 DRILL P SURF 01 :30 - 05:00 3,50 DRILL P SURF 05:00 - 09:30 4.50 DRILL P SURF 09:30 - 12:00 2.50 DRILL P SURF 12:00 - 14:30 2.50 DRILL P SURF 14:30 - 16:00 1.50 DRILL P SURF 16:00 -18:00 2.00 DRILL P SURF 18:00 - 18:30 0.50 DRILL P SURF 18:30 - 20:00 1.50 DRILL P SURF 20:00 - 20:30 0.50 DRILL P SURF 20:30 - 21":30 1.00 DRILL P SURF 21 :30 - 22:00 0.50 DRILL P SURF 22:00 - 22:30 0.50 CASE P SURF 22:30 - 00:00 1.50 CASE P SURF 9/13/2003 00:00 - 00:30 0.50 CASE P SURF 00:30 - 01 :30 1.00 CASE P SURF 01 :30 - 03:30 2.00 CASE P SURF 03:30 - 16:00 12.50 CASE P SURF 16:00 - 16:30 0.50 CASE P SURF 16:30 - 19:30 3.00 CASE P SURF 19:30 - 20:05 0.58 CEMT P SURF 20:05 - 21 :25 1,33 CEMT P SURF Start: Rig Release: Rig Number: 9/9/2003 9/23/2003 Spud Date: 9/10/2003 End: 9/23/2003 . . . ... Description ofOperation!!f Reciprocate DP at 100 rpm. 116 klbs up, 61 klbs down, 71 klbs rotate. Backream out from TD at 4344, 650 gpm @ 3280 psi and 80 rpm. Back ream out until a total of 3 bottoms up circulations have been pumped at 4158'. POH from 4158' to 3960'. Started pulling 25 klbs over at 3960' Backream out from 3960' to the base of the permafrost at 2550'. 660 gpm @ 2550 psi and 80 rpm Attempt to POH, hole started swabbing. MU top drive and pump out without rotating from 2550' to 600'.650 gpm @ 2590 psi. POH to jar stand, work through obstruction at 520' RIH. Hit obstruction at 970' continue RIH working obstruction to bottom. Wash down from 4175' to TD at 4344' Break circulation and stage up pumps to 650 gpm @ 3450 psi. Pump weighted sweep surface to surface while reciprocating DP at 100 rpm. 120 klbs up, 65 klbs down, 81 klbs rotate, 7 klbs torque. Without pumps 124 klbs up, 59 klbs down. Begin backreaming out while circulating bottoms up to 4150'. 650 gpm @ 3450 psi and 80 rpm POH. Work and wipe through tight spots at 2240' and 2150'. Pulled tight at 1550' unable to work trhough. MU top drive and stage up pumps to 650 gpm @ 1900 psi. Pump out without rotating to 1335'. Pulled tight while pumping out at 1335', started backreaming at 50 rpm. Backream to 1242' POH from 1242' to the HWDP. Stand back HWDP, jar and collar stands. Flush MWD and motor. break bit. LD BHA Clean and clear rig floor. PJSM with Nabors Casing and all rig personnel on rigging up and running casing. Change out bails. RU 9-5/8" casing equipment. MU fill-up tool. Continue RU 9-5/8" 40# casing equipment. Make dummy run with landing joint. Baker-Lok float equipment and check floats Run 9-5/8" 40# casing to 1430' as per running orders. At 1430' hit obstruction, work and wash casing through obstruction. 300 gpm @ 350 psi. Continue running casing working and washing to TD at 4334'. Intermintent tigh spots throughout, worked through tight spots at the following depths: 1430',1650',2724' and 4154' PU landing joint and land casing at 4334". RD fill-up tool. RU cement head. Stage pumps to 9-1/2 bpm @ 540 psi. Ciculate and condition mud while reciprocating casing. 193 klbs up, 89 klbs down. Pump 5 bbl CW100 chemical wash. Pressure test lines to 3500 psi. Pump 15 bbls CW100 chemical wash followed by 80 bbls Mud Push II at 10.5 ppg - 5 bpm @ 150 psi Drop bottom plug. Batch up and pump 553 bbls (735 sxs) 10.7 ppg ARCTICSET Lite III lead cement. Started pumping at 7 bpm @ 250 psi reduced rate to 6 bpm @ 230 psi to allow returns to go to a vac truck, Printed: 9/2912003 9: 14: 13 AM .... - i,BP .." Operat'..ons Summary Report" Page 3 of9 Legal Well Name: W-215i' Common Well Name: W-215i Spud Date: 9/10/2003 Event Name: DRILL +COMPLETE Start: 9/9/2003 End: 9/23/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/23/2003 Rig Name: NABORS 9ES Rig Number: Date From "To I Hours Task Code NPT I Phase Descriþtîön:of Operations . . ... .... . t . . I , , ¡ ._~_._. 9/13/2003 20:05 - 21 :25 1.33 CEMT P SURF Able to reciprocate casing up to this point. Started pulling heavy with cement around shoe, had to work casing back onto ring while reciprocating. Landed casing on hanger for remainder of job. 21 :25 - 21 :50 0.42 CEMT P SURF Pump 87 bbls (432 sxs) 15.8 ppg Class G tail cement at 4 bpm @ 150 psi final pressure. 21 :50 - 21 :55 0.08 CEMT P SURF Drop top plug and kick out with 10 bbls of water from cement unit to wash lines. 21 :55 - 22:40 0.75 CEMT P SURF Switch to rig pumps and displace cement with mud. Stage pumps to 9 bpm @ 500 psi. Pump 300 bbls and reduce rate to 2 bpm @ 450 psi to bump. Started getting good cement returns 4000 strokes into displacement. Bump plugs on calculated strokes with 1000 psi. 30 bbls cement returns to surface. Bleed off pressure and check floats - holding. CIP: 22:40 hrs. 22:40 - 00:00 1.33 CEMT P SURF Flush stack and flowline. Blow down cement lines. RD cement head. 9/14/2003 00:00 - 02:00 2.00 CASE P SURF RD casing equipment. Change out bails 02:00 - 05:00 3.00 DIVRTR P SURF NO diverter, diverter line, riser and Hydril. Move riser and diverter out of cellar. 05:00 - 06:00 1.00 WHSUR P PROD1 NU speed head, adapter flange and tbg spool. Test metal to metal seal to 1000 psi. 06:00 - 08:00 2.00 BOPSURP PROD1 NU BOPE and riser 08:00 - 09:00 1,00 BOPSURP PROD1 Jack up rig and pits. Shim up both sections to level after settling 09:00 - 09:30 0.50 BOPSURP PROD1 Rig up BOPE test equipment 09:30 - 13:00 3.50 BOPSUR P PROD1 Test BOPE 250 psi low/4000 psi high for all rams, lines, valves and choke manifold. Test annular to 250 psi low/3500 psi high. Witness of BOP test waived by Jeff Jones with AOGCC. 13:00 - 13:30 0.50 BOPSURP PROD1 RD BOPE test equipment, blow down lines, Install wear bushing, 13:30 - 18:00 4,50 DRILL P PROD1 PU DP singles from shed RIH to 3332'. POH standing back 36 stands. 18:00 - 19:30 1.50 DRILL P PROD1 Cut & slip 65' of drilling line. Service top drive and blocks. 19:30 - 20:00 0.50 DRILL P PROD1 PJSM with Anadrill and all rig personnel on PU/MU BHA and loading RA source. 20:00 - 22:00 2.00 DRILL P PROD1 MU BHA #3. Orient MWD tools. Load RA source. 22:00 - 23:00 1.00 DRILL P PROD1 RIH with HWDP. MU ghost reamer. Shallow test MWD tools 550 gpm @ 1300 psi 23:00 - 00:00 1.00 DRILL P PROD1 RIH picking up DP singles from pipe shed 9/15/2003 00:00 - 02:30 2.50 DRILL P PROD1 Continue RIH to 4115' picking up DP from shed. Pressure test casing to 1000 psi after bit and ghost reamer are past TAM port 02:30 - 03:30 1.00 CASE P PROD1 Fill pipe. Break circulation. Shut in well and test casing to 3500 psi for 30 minutes 03:30 - 04:30 1.00 DRILL P PROD1 Wash down from 4115 and tag cement at 4225'. Drill cement to 4333'. Tag float collar at 4247' 04:30 - 04:45 0.25 DRILL P PROD1 Tag the float shoe at 4332'. Drill the shoe and rathole to 4344' 04:45 - 05:00 0.25 DRILL P PROD1 Drill 20' of new hole from 4344' to 4364'. 115 klbs up, 60 klbs down, 78 klbs rotate. 500 gpm @ 2100 psi, 40 rpm, 7.5 klbs torque, WOB 5 klbs. 05:00 - 06:00 1,00 DRILL P PROD1 Displace to new 9.0 ppg LSND mud. 600 gpm @ 1900 psi, 100 Printed: 9/29/2003 9:14:13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 9/15/2003 05:00 - 06:00 06:00 - 06:30 06:30 - 07:00 07:00 - 00:00 9/16/2003 00:00 - 23:00 23:00 - 00:00 . . Page4 of 9 .... . BP ... .. .. .... . . ... . . . .. ... . Operations Summary Report W-215i' W-215i DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Hours I Task CodeNPT 1.00 DRILL P 0.50 DRILL P 0,50 DRILL P 17.00 DRILL P 23.00 DRILL P 1.00 DRILL P Start: Rig Release: Rig Number: Phase, 9/9/2003 9/23/2003 Spud Date: 9/10/2003 End: 9/23/2003 Description ofOperatiol1s . . . PROD1 rpm PROD1 Pull bit inside 9-5/8" casing, Perform LOT. 380 psi surface pressure, EMW = 11.7 ppg PROD1 RIH to put bit just outside of 9-5/8" csg. Stage pumps to drilling rate of 600 gpm and establish baseline ECD of 9.9 ppg PROD1 Directional drill from 4364' to 6940'. 595 gpm @ 3060 psi. 115 klbs up, 78 klbs down, 97 klbs rotate. 10-20 klbs WOB, 6-7 klbs torque, Calculated ECD 10.16 ppg, Actual ECD = 10.96 ppg. Inclination dropping 1-3 degrees per 100' while rotating, slide 20'-40' every 2 to 3 stands to maintain inclination at -63.5 degrees. Backream every stand at 595 gpm and 100 rpm, reduce flow to 450 gpm on down stroke. Circulate hi-vis sweep every 300', Circulate as needed to maintain actual ECD's within 1.0 ppg of calculated. AST last 24 hrs. = 2.10 hrs. ART last 24 hrs. = 4.21 hrs. Total drilling time = 6.31 hrs. -1/2 hour of problem time due to faulty MWD IRCT cable to rig floor MWD display, cable replaced. Not carried as NPT time due to the fact that the wellbore was being circulated to reduce ECD's during this time, no actual lost time. Anadrill MWD lost communication with the ADN tool at -10:30, Co. Rep was not informed of the situation until 19:30. Calls were made to the Drilling Engineer and Anchorage geology staff, the decision was made to continue drilling to the top of the Schrader with the possibility communications could be reestablished. There is a -50% chance the data is still being recorded and can be downloaded on surface. At the top of the Schrader it will be decided if a trip for MWD is needed. PROD1 Directional drill from 6940' to 10,594' (TD). 595 gpm @ 3330 -3860 psi. 165 klbs up, 86 klbs down, 121 klbs rotate. 10-20 klbs WOB, 10-12.8 klbs torque. Calculated ECD 10.26 ppg, Actual'ECD = 10.86 ppg. AST: 2.47 hrs; ART: 9.24 hrs Inclination dropping 1-3 degrees per 100' while rotating, slide 20'-40' every 2 to 3 stands to maintain inclination at -63.5 degrees. Backream every stand at 595 gpm and 100 rpm, reduce flow to 450 gpm on down stroke. Circulate sweep every 300', vary between hi-vis, low vis/high vis and weighted sweeps, Circulate as needed to maintain actual ECD's within 1.0 ppg of calculated. Added total of 600 bbls new 9.0 ppg LSND mud to system. PROD1 Pump sweep. Circ & cond hole. Pumped a total of 2 BU after sweep. Reciprocate DP @ 110 RPM w/ same parameters as Printed. 9/29/2003 9:14:13 AM . . Page 5 of 9 BP < ()peratiC)ns Summê!ryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-215i' W-215i DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Date ¡ I I From - To Hours ¡ Task ¡ Code,NPT Phase _._._-------~._...__._.- - 9/16/2003 23:00 - 00:00 1.00 DRILL P PROD1 9/17/2003 00:00 - 02:00 2.00 DRILL P PROD1 02:00 - 02:30 0.50 DRILL P PROD1 02:30 - 04:30 2.00 DRILL P PROD1 04:30 - 10:00 5.50 DRILL P PROD1 10:00 - 13:00 3.00 DRILL P PROD1 13:00 - 14:00 1.00 DRILL P PROD1 14:00 - 14:30 0.50 DRILL P PROD1 14:30 - 17:30 3.00 DRILL P PROD1 17:30 - 22:30 5.00 DRILL P PROD1 22:30 - 00:00 1.50 DRILL P PROD1 9/18/2003 00:00 - 03:30 3.50 DRILL P PROD1 03:30 - 05:30 2.00 DRILL P PROD1 05:30 - 06:00 0,50 BOPSUR P PROD1 06:00 - 07:30 1.50 BOPSURP PROD1 07:30 - 09:00 1.50 CASE P PROD1 09:00 - 09:30 0,50 CASE P PROD1 09:30 - 15:00 5.50 CASE P PROD1 15:00 - 16:00 1.00 CASE P PROD1 16:00 - 00:00 8.00 CASE P PROD1 9/19/2003 00:00 - 02:00 2.00 CASE P PROD1 02:00 - 02:30 0.50 CASE P PROD1 02:30 - 05:00 2.50 CASE P PROD1 05:00 - 07:30 2.50 CEMT P PROD1 Start: Rig Release: Rig Number: Spud Date: 9/10/2003 End: 9/23/2003 9/912003 9/23/2003 Descriptìåri, of Operations above. Continue circ sweep around @ 594 GPM & 110 RPM. Continue f/2 BU. Monitor well-OK. Calc ECD: 10.28; Actual: 10.47 POH. Wipe spot @ 10,370'-OK. POH to 10,200'. Started overpull. RIH to 10,300'. Break circ. Stage pumps up to 585 GPM. Initial ECD: 10.7 ppg. Start backreaming out to 9655' w/120 RPM. Final ECD: 10.47 ppg. POH slow to 5200'. Pull slow to control swabbing. Started swabbing @ any speed. RIH to 5300'. Backream out to shoe. Same parameters as previous. Final ECD: 10.68 ppg. Service Top drive blocks and crown. Change wash pipe. CBU @ 600 gpm , 2070 psi, 60 rpm, TQ-4.5k. Final ECD 9.97 RIH. Work throught tight spot @ 7630-0K. RIH. Wash last stand to bottom-No fill. Calc ECD: 10.26; Actual: 10.95. Circulated and swept hole @ 570 gpm , 3970 psi. Reciprocated w/110-120 RPM. Staged up to 600 gpm and 3470 psi. Pressure dropped back as hole cleaned up. After sweep pumped S/S and shakers clean, rotary torque @ 15k. Pumped another Hi vis sweep S/S monitoring torque. Followed sweep with an added 1 % lubetex attempting to reduce rotary torque. Hole conditions were clean so added 4 drums EP-mudlube. Rotary torque dropped to 10k ftjlbs final reading. Spotted 10lbs/bbl. G-Seal in open hole while recip, DP at 120 rpm. Lubes 4%. Initial ECD: 10.97; Final 1 0.13 calc. Monitor we I-OK. POOH to 10,100. First 5 stands pulled good. Continue POH to shoe. Hole in good shape. Monitor well-OK, POH to HWDP. Stand back HWDP. LD BHA. Unload nuclear source. Break bit. Clear rig floor. Pull wear ring. Flush stack w/ ported sub. Set test plug. Change top rams to 7". Test to 3500 psi-OK. Pull test plug. PU landing jt & make dummy run. RU casing tools. PJSM w/ crew on running 7", MU shoe track. Check floats-OK. RIH w/ 7" casing to 9 5/8" shoe. Fill every jt. Circ f/10 min 1/2 way to shoe. No losses. Stage pumps up slowly to 7 BPM w/ 460 psi. 4 BPM w/190 psi. Circ 1.5 x BU. No losses. Continue RIH @ 1 min / jt, filling every jt. Break circ every 20 jts. CBU while running in slowly f/6000' to 6700'. CBU while running in slowly f/ 8000' to 8800'. Continue RIH filling every jt to 9050' Continue running 7" casing f/9050' to 10,580', Broke circulation every 20 jts. Made up landing jt and landed. No losses running pipe. Ran a total of 255 jts, 7", 26#, L-80 BTC-Mod casing. RD Frank's tool. MU cement head. Blow down top drive. Break circ slowly and stage up to 8 bpm & 820 psi.. Reciprocate w/ 202k PUW & 105k SOW. Circ all the way around. Batch mix cement while circulating. Cement w/10 bbls CW 100; 30 bbls MudPush II @ 10.3 ppg; & 93 bbls (430 sxs) Premium 'G' @ 15.8 ppg. Pumped cement @ 6 bpm. Displace w/ seawater @ 7 bpm f/ 325 bbls; 6 bpm f/ 27 bbls; 3 bpm f/ 20 bbls; & 1 bpm f/ 28 bbls, FCP = Printed, 9/29/2003 9:14:13 AM . . Page 6 of 9 BP ,Op~råtions Summary Report PROD1 1260 psi. Displaced cement with 401 bbl total fluid. Bumped plug with 2260 psi. CIP @ 06:55 hrs. Bled off surface pressure. Floats held. Monitor well while preparing to RD cement related equipment. RD cement head. Blow down surface lines. Pull & LD 7" casing landing joint. RD casing running equipment & change out elevator bails, PU running tool, set wellhead pack-off, pressure test to 5000 psi for 10 minutes. Held PJSM. Change upper rams in BOP from 7" to 3.5" x 6" VBR. MU test plug on 4" DP & land in wellhead. Test 3.5" x 6" VBR's to 3500 psi. Pull test plug & install wearbushing. TIH with 8.5" bit, FS, XO & 7 std of HWDP to 649'. Slip & cut 87' of drill line. Reset & check C-O-M. Service TDS, Continue TIH with 8.5" clean out assembly on 4" DP to 10450' (Fill DP @ 5300'), Establish circulation. Wash down from 10450'. Tag up on float collar @ 10495'. Pump 8 bbl Dirt Magnet pill + 50 bbl HV Seawater sweep followed by clean 9.3 ppg brine water. Pump rate 13 bpm with 3300 psi. Rotate & reciprocate drill string while displacing well with 9.3 ppg brine. COMP POOH to 7015'. Stand back 37 stands of 4" DP in derrick. COMP POOH. UD 4" DP. Note: Performed the following while POOH. RlU 9ES mud pump on 9 5/8 X 7' annulus, Test lines to 3500 psi. With Rig pump bullhead 185 bbls of 9.3 ppg mud down annulus Start at 1 bbl/min @ 600 psi. - complete at 4 bblJ min @ 850 psi. RlU hot oiler and test lines to 3500 psi. Bullhead 93 bbls of dead crude down annulus. Max rate 3 bbl/min, max pressure 1000 psi S/I with 750 psi. RID hot oiler & secure wellhead wing valves, Finish POOH. Stand back 4" HWDP. UD bit, float sub & XO sub. Held PJSM. Pull wearbushing, run test plug. Change upper rams in BOP from 3.5" x 6" VBR to 7" casing rams. Test bonnet seals to 3500 psi. Pull test plug & install wearbushing. RlU to test 7" casing. Pressure up on 7" casing (5.5 bbl) to 4000 psi. Hold for 30 minutes & record on chart. Test was API. SAFETY ---. Held PJSM with Rig Crew & Schlumberger E-line crew regarding rigging up e-line logging equipment, lubricator & the pressure testing of lubricator. RlU Schlumberger e-line sheaves & related equipment. Install 7" lubricator & test to 1 000 psi. Run US IT log to 10485'. Log up with same to 7600' (TOC @ 7775'). POOH. UD US IT logging tool. SAFETY --. Held PJSM with Rig Crew & Schlumberger E-line crew regarding perforating operations. M/U Perf Guns for run #1. (20' of 4-1/2" HSD PowerJet charge guns @ 5 spf). RIH. Log on depth. Perforate 7" casing (Obc sand zone) F/10012'-9992'. Monitor well after firing guns. Well static. POOH. Had 100% detonation on perf guns. UD spent perf guns. M/U Perf Guns for run #2. RIH. Log on depth. Peforate 7" casing (Obc sand zone) F/9992'-9972'). Monitor Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-215i' W-215i DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Date From ~ To Hours Task Code NPT Phase ------ --......----.- .-- 9/19/2003 05:00 - 07:30 2,50 CEMT P 07:30 - 09:30 2.00 CEMT P PROD1 09:30 -10:30 1,00 WHSUR P COMP 10:30 - 12:00 1.50 BOPSUR P COMP 12:00 -12:30 0.50 CLEAN P COMP 12:30 - 14:00 1.50 CLEAN P COMP 14:00 -17:30 3.50 CLEAN P COMP 17:30 - 18:30 1,00 CLEAN P COMP 18:30 - 20:30 20:30 - 00:00 2.00 CLEAN P 3.50 CLEAN P 9/20/2003 00:00 - 00:30 0.50 CLEAN P COMP 00:30 - 02:00 1.50 BOPSURP COMP 02:00 - 03:00 1.00 CASE P COMP 03:00 - 03:30 0.50 EVAL P COMP 03:30 - 05:00 1.50 EVAL P COMP 05:00 - 09:00 4.00 EVAL P COMP 09:00 - 09:30 0.50 PERF P COMP 09:30 - 13:30 4.00 PERF P COMP Start: Rig Release: Rig Number: 9/9/2003 9/23/2003 Spud Date: 9/10/2003 End: 9/23/2003 Description of Operations _______.w__.._...." Printed, 9/29/2003 9,14,13 AM Legal Well Name: ' Common Well Name: Event Name: Contractor Name: Rig Name: -~ - Page 7 of 9 BP Operations Summary a.eport . ... W-215i' W-215i DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: Spud Date: 9/10/2003 End: 9/23/2003 9/912003 9/23/2003 Date From - To Hours: Task Code NPT Phase 9/20/2003 09:30 - 13:30 4.00 PERF P COMP 13:30 - 16:00 2.50 PERF N DFAL COMP 16:00 - 18:00 18:00 - 00:00 9/21/2003 00:00 - 02:30 2.00 PERF P COMP 6.00 CLEAN P COMP 2.50 CLEAN P COMP 02:30 - 03:00 0.50 BOPSURP COMP 03:00 - 04:30 1.50 BOPSURP COMP 04:30 - 05:30 1.00 RUNCOI'vP COMP 05:30 - 06:00 0.50 RUNCOI'vP COMP 06:00 - 07:00 1,00 RUNCOI'vP COMP 07:00 - 08:30 08:30 - 00:00 9/22/2003 00:00 - 00:30 00:30 - 01 :00 1.50 RUNCOI'vP COMP 15.50 RUNCOI'vP COMP 0.50 RUNCOI'vP COMP 0.50 RUNCOI'vP COMP Description of Operations well after firing guns. Well static. POOH. PERF GUNS DID NOT FIRE, UD same. M/U fresh set of perf guns. RIH (Perf gun run #3). Log guns on depth. Perforate 7" casing (Obc sand zone) F/9992'-9972'). Monitor well after firing guns. Well static. POOH. Had 100% detonation on perf guns. M/U Perf Guns for run #4. (30' of 4-1/2" HSD PowerJet charge guns @ 5 spf). RIH. Log on depth. Perforate 7" casing (Oba sand zone) F/9855'-9825'. Monitor well after firing guns. Well static. POOH. Had 100% detonation on perf guns, UD spent perf guns. Schlumberger M/U Junk Basket with 6.140" gauge ring. RIH to 10300' (Encountered resistance while RIH with GRlJB from 9825' to 10012'). POOH. Recovered a significant amount of debris from Junk Basket. Ran Junk Basket 2 additional times with each run yielding less debris from well. RIH with 6.140" Gauge Ring/Junk Basket (Run #4) to 10300'. POOH. Recovered 1 tablespoon of debris. Total debris recovered = +/- 5 Ib, RID Schlumberger e-line equipment & lubricator. Pull wearbushing, Make a dummy run with 11" x 4.5" FMC tubing hanger. Run & set BOP test plug. Held PJSM. Change out upper rams from 7" casing rams to 3.5" x 6" VBR. Test bonnet seals to 3500 psi. RlU to run 3.5" x 4.5" completion string. Change out elevator bails. RlU Nabors tubing running & Torque-Turn equipment. Held PJSM with Rig Crew, Schlumberger TCP & Nabors Tubing Tong Service Rep regardin'g picking up TCP guns & tubing running operations. M/U Schlumberger SXAR Gun Drop assembly consisting of 3 each 4-1/2" HSD PowerJet 4505 HMX 38.8 5 spf @ 72 deg phasing + 1 each Blank Gun (Safety Spacer) + Auto-release SXAR + TCF Firing Head + Debris Sub. Total length = 95.75'. Change over to run 3.5" tubing. RIH with 3.5" Tail-pipe & X-nipple assembly + 3.5" 9.3# L-80 TCII tubing with Baker 7" Stratle Packers & GLM (4each) assemblies (Packers spaced out to be set @ 10029' & 9870').Totallength = 435.25'. Change over to run 4,5" tubing. Continue RIH with SXAR Gun Drop assembly + 3.5" tubing w/ 7" Stradle Packer assemblies (Packers spaced out to be set @ 10029',9870' & Top Packer @ 9625') on 4.5" 12.6# L-80 TC-II production tubing to 9960' @ 1 minute/Jt. Avg M/U torque on 4.5" tubing = 2700 FULb using Jet-Lube Seal Guard pipe dope. Finish RIH with SXAR Gun Drop assembly + 3.5" tubing w/ 7" Straddle Packer assemblies (Packers spaced out to be set @ 10029',9870' & Top Packer @ 9625') on 4.5" 12.6# L-80 TC-II production tubing to 10144' @ 1 minute/Jt. P/U & install FMC tubing hanger in string. P/U Wt 123k, S/O Wt 69k. Land Hanger & production string placing bottom of assembly @ 10169' DPM. NOTE: Top connection on tubing hager is 4-1/2" TCII SAFETY --- Held PJSM with Rig Crew & Schlumberger E-line crew regarding rigging up e-line logging equipment & lubricator Printed: 9/29/2003 9: 14: 13 AM . . Page 8 of 9 BP Operations S~mmary ¡Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date W-215i' W-215i DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES From - To Hours Task I Code NPT I Start: Rig Release: Rig Number: Phase -.--.--....--.....----...-. -- 9/22/2003 00:30 - 01 :00 01 :00 - 02:00 02:00 - 05:00 0.50 RUNCOIvP 1.00 RUNCOIvP 3.00 RUNCOIvP caMP caMP COMP 05:00 - 07:00 2,00 RUNCOIvP COMP 07:00 - 07:30 0.50 RUNCOIvP COMP 07:30 - 08:30 1.00 RUNCOIvP COMP 08:30 - 11 :00 2.50 RUNCOII/I'II WAIT COMP 11 :00 - 12:00 1.00 RUNCOII/I'II DPRB COMP 12:00 - 13:00 13:00 -17:00 1.00 RUNCOII/I'II 4.00 RUNCOII/I'II DPRB COMP DPRB caMP 17:00 - 18:00 1.00 RUNCOIvP COMP 18:00 - 18:30 0,50 RUNCOIvP COMP 18:30 -19:30 1.00 RUNCOIvP COMP 19:30 - 20:00 0.50 RUNCOIvP COMP 20:00 - 21 :30 1.50 BOPSUR. P COMP 21 :30 - 23:30 2.00 WHSUR P COMP 23:30 - 00:00 0.50 WHSUR P COMP 9/23/2003 00:00 - 00:30 0.50 WHSUR P caMP 00:30 - 03:00 2.50 WHSUR P COMP 03:00 - 04:00 04:00 - 05:00 1.00 WHSUR P 1.00 WHSUR P COMP COMP 9/9/2003 9/23/2003 Spud Date: 9/10/2003 End: 9/23/2003 Description of Operations for running the GR-CCL tool. RlU Schlumberger e-line sheaves & lubricator system. Schlumberger RIH with PBMS (GR-CCL) tool to 10050'. Run correlation pass from 10050' to 9600'. POOH. RID Lubricator & e-line equipment. Correlation log indicates that TCP guns set to fire from 10166'-10096'. Reverse circulate down annulus & up tubing with 223 bbl of clean 9.3 ppg NaCI followed by 121 bbls of 9.3 ppg corrosion inhibited brine @ 3 bpm w/ 275 psi. RID tubing pump-in sub. Drop Ball-rod & allow to gravitate on seat while UD the Tubing Landing Jt. Pump down tubing & attempt to set lower 'S-3' packer. All indications ball not on seat. Reverse circulate in an attempt to move ball-rod, then line up & pump down tubing again to seat ball. Unable to seat ball. Wait on Halliburton Slick-line personnel & equipment to arrive at location. Change elevator bails, service TDS, change out & test lower TIW valve on TDS. M/U tubing Landing Jt into tubing hanger & install TIW valve in preparation to run Slick-line, SAFETY --- Held PJSM with Rig Crew & Halliburton Slick-line personnel regarding rigging up & slick-line operations. R/U Halliburton Slick-line & related equipment. Halliburton Slick-line RIH with a 2.7" OD Lead Impression block. Tag up @ 9814'. Work impression block through GLM, continue RIH. Tag up again @ 9954'. Work impression block through GLM, continue RIH. Tag up @ 9980 & work down to 9991". POOH with slick-line. Had good indication that Lead Impression block was pushing ball-rod Pressure up on tubing. Ball-rod on seat. Continue pressuring tubing to 4000 psi. Hold test for 30 minutes. Test was API. Manually bled off tubing pressure to 1000 psi. RID Halliburton Slick-line equipment. Repressure tubing to 3000 psi. Pressure up 4.5 x 7" annulus to 4000 psi. Hold test for 30 minutes. Test was API. Manually bled off pressure on both tubing & annulus to 0 psi. Pressure up 4.5" x 7" annulus to 2600 psi & sheared DCK valve in the GLM @ 5256'. Pump @ 2 bpm with 2100 psi. Pump pressure indicates partial shear. Pump out BOP. FMC install TWCV. Test same to 1000 psi-OK. PJSM. N/D BOP's. Set back & secure. N/U FMC 11" 5K x 4-1/16" 5K Tubing head adapter & 4-1/16" 5K Production Tree. Test tubing head adapter & tree to 5000 psi. RlU DSM Lubricator to pull TWCV. DSM pull TWCV. Held PJSM with Rig Crew & Little Red Hot Oil service rep regarding freeze protecting operations. RlU Hot Oil & test lines to 3000 psi. Freeze protect 4.5" x 7" annulus. Reverse circulate 105 bbl of diesel down 4,5" x 7" annulus @ 3.5 bpm with 2300 psi. Let well U-Tube & equalize. DSM install BPV in Tubing Hanger. Test to 1000 psi. RID Hot Oil line & DSM. Secure Well. RID & prepare for rig move. Released Nabors Rig 9ES from well # W-215i at 05:00 Printed: 9/29/2003 9:14:13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . . BP Operations Summary RèP9rt W-215i' W-215i DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 9/9/2003 Rig Release: 9/23/2003 Rig Number: Qate,From - To Hours Task ,Gode,NPT Phase' 9/23/2003 04:00 - 05:00 05:00 - 06:00 ..~.._...-.~..~--~----- 1.00 WHSUR P 1.00 RIGD P -..-.-.....-----..-. Page 9 of 9 Spud Date: 9/10/2003 End: 9/23/2003 Description of Operations, COMP hrs on 9/23-2003. COND1 RDMO Nabors 9ES from well W-215i to W-209i. Printed: 9/29/2003 9:14:13 AM (~03'--) 3 \ W-215PB1 Survey Report Schlu berger . Report Date: 12-Sep-03 Client: B P Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure 1 Slot: W-PAD 1 W-215 Well: W-215 Borehole: W-215PB1 UWVAPI#: 500292317270 Survey Name 1 Date: W-215PB11 September 12, 2003 Torti AHD/DDI/ERD ratio: 32.842' 1299.93 ft/4.0121 0,228 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LatILong: N 70.29772700, W 149.09260204 Location Grid NIE Y/x: N 5959290.840 ftUS, E 612048.970 ftUS Grid Convergence Angle: +0.85428445' Grid Scale Factor: 0,99991426 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Vertical Section Azimuth: 70.750' Vertical Section Origin: N 0,000 ft, E 0.000 ft TVD Reference Datum: KB TVD Reference Elevation: 80.80 ft relative to MSL Sea Bed 1 Ground Level Elevation: 52.30 ft relative to MSL Magnetic Declination: 25.337' Total Field Strength: 57551,855 nT Magnetic Dip: 80.806' Declination Date: September 18, 2003 Magnetic Declination Model: BGGM 2003 North Reference: True North Total Corr Mag North -> True North: +25.337' Local Coordinates Referenced To: Well Head C· r~"f" ~_.~ l'., .!¡ j j-" J ~,.,f . Comments Measured I Inclination I Azimuth I Course TVD I Sub-Sea TVD I Vertical I NS EW Closure I Closure I DLS I Northing Easting Latitude Longitude Depth Length Section Azimuth (II) ( deg) ( deg) (II) (II) (II) (II) (II) (II) (II) ( deg) (deg/100 II) (IIUS) (IIUS) 0.00 0.00 0.00 0.00 0.00 -80.80 0.00 0.00 0,00 0.00 0.00 0.00 5959290.84 612048.97 N 70,29772700 W 149.09260204 198.26 0.48 77.98 198.26 198.26 117.46 0,82 0.17 0.81 0.83 77.98 0.24 5959291.03 612049.78 N 70.29772748 W 149.09259547 291 .55 2.79 81,56 93.29 291.50 210,70 3.44 0.59 3.44 3.49 80.31 2.48 5959291.48 612052.40 N 70.29772861 W 149.09257418 384.88 4.37 79.19 93.33 384.65 303.85 9.19 1.59 9.18 9.32 80.19 1.70 5959292.56 612058.13 N 70,29773134 W 149.09252771 477.17 6.11 78.09 92.29 476.55 395.75 17.54 3.26 17.44 17.74 79.41 1.89 5959294.36 612066,36 N 70.29773591 W 149.09246082 570.26 7.75 72.69 93.09 568.96 488.16 28.73 6.15 28.28 28.94 77.73 1.89 5959297.41 612077.15 N 70.29774381 W 149.09237304 663.14 9.46 70,47 92.88 660,79 579.99 42.62 10.57 41.45 42.78 75.70 1.88 5959302.02 612090.26 N 70.29775587 W 149.09226637 756.53 11.85 67.53 93.39 752,56 671 .76 59.87 16.80 57.55 59.95 73.73 2.62 5959308.49 612106.26 N 70.29777289 W 149.09213604 847.68 14.84 70.40 91.15 841.24 760.44 80.89 24.29 77.20 80.93 72.53 3.36 5959316.28 612125.79 N 70.29779337 W 149.09197693 940.53 18,16 71.59 92,85 930,26 849.46 107.26 32.85 102.14 107.29 72.17 3.59 5959325,21 612150.60 N 70.29781675 W 149.09177501 1033.56 22.91 71,81 93.03 1017,35 936,55 139.88 43,09 133.11 139.91 72.06 5.11 5959335.91 612181.42 N 70.29784472 W 149.09152419 . 1127.35 26.13 72,37 93.79 1102.67 1021.87 178.79 55.05 170,15 178,83 72.07 3.44 5959348.41 612218.27 N 70.29787738 W 149.09122430 1220.85 28,25 71.58 93.50 1185.83 1105.03 221,50 68.28 210.77 221.55 72.05 2.30 5959362.25 612258.68 N 70.29791352 W 149.09089539 1314.24 32.43 70.19 93.39 1266.42 1185.62 268.66 83.75 255,32 268,71 71.84 4.54 5959378.38 612302.99 N 70.29795580 W 149.09053466 1372,00 32.43 70.19 57.76 1315.17 1234.37 299,63 94.25 284.46 299.67 71.67 0.00 5959389,31 612331.97 N 70,29798448 W 149,09029869 Leqal Description: Northinq (Y) [ftUS] Eastinq (X) [!tUS] Surface: 4313 F8L 1186 FEL 821 T11N R12E UM 5959290.84 612048.97 BHL: 4408 F8L 901 FEL 821 T11 N R12E UM 5959389,31 612331.97 Version DO 3.1 RT ( do31 rL546 ) 3.1 RT-8P3.03 W-215\W-215\W-215PB1\W-215PB1 Generated 10/212003 4:47 PM Page 1 of 1 -R~f\¡\b W-215 Survey Report Schlu puep Report Date: 17 -Oct-03 Survey 1 DLS Computation Method: Minimum Curvature 1 Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 71.070' Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure 1 Slot: W,PAD/W,215 TVD Reference Datum: KB Well: W-215 TVD Reference Elevation: 80.80 ft relative to MSL Borehole: W-215 Sea Bed 1 Ground Level Elevation: 52.30 ft relative to MSL UWVAPI#: 500292317200 Magnetic Declination: 25.345' Survey Name 1 Date: W-2151 September 17, 2003 Total Field Strength: 57551.282 nT Tort 1 AHD 1 DDII ERD ratio: 140.466' 18448.45 ft / 6.351 /1.508 Magnetic Dip: 80.806' Grid Coordinate System: NA027 Alaska State Planes, Zone 04, US Feet ÐeeIinaIion Date: September 11 , 2003 Location LatILong: N 70.29772700, W 149.09260204 Magnetic Declination Model: BGGM 2003 Location Grid NIE YIX: N 5959290.840 ftUS, E 612048.970 ftUS North Reference: True North . Grid Convergence Angle: +0.85428445' Total Corr Mag North -> True North: +25.345' Grid Scale Factor: 0.99991426 Local Coordinates Referenced To: Well Head Comments Measured I Inclination I Azimuth I Course I TVD I Sub-Sea TVD I Vertical I NS EW Closure I Closure I DLS I Northing Easting Latitude Longitude Depth Length Section Azimuth (It) (deg) (deg) (It) (It) (It) (It) (It) (It) (It) (deg) (degl100 It) (ltUS) (ltUS) 0.00 0.00 0.00 0.00 0.00 -80.80 0.00 0.00 0.00 0.00 0.00 0.00 5959290.84 612048.97 N 70.29772700 W 149.09260204 198.26 0.48 77.98 198.26 198.26 117.46 0.82 0,17 0.81 0.83 77.98 0.24 5959291,03 612049.78 N 70.29772748 W 149.09259547 291.55 2.79 81.56 93.29 291.50 210,70 3.45 0.59 3.44 3.49 80,31 2.48 5959291.48 612052.40 N 70.29772861 W 149.09257418 384.88 4.37 79.19 93.33 384.65 303.85 9.20 1.59 9.18 9,32 80.19 1.70 5959292,56 612058.13 N 70.29773134 W 149.09252771 477.17 6.11 78.09 92.29 476.55 395.75 17.56 3.26 17.44 17.74 79.41 1.89 5959294.36 612066.36 N 70.29773591 W 149.09246082 570.26 7.75 72.69 93.09 568.96 488.16 28.75 6.15 28.28 28.94 77.73 1.89 5959297.41 612077.15 N 70.29774381 W 149.09237304 663.14 9.46 70.47 92.88 660.79 579.99 42.64 10.57 41.45 42.78 75.70 1.88 5959302.02 612090.26 N 70.29775587 W 149.09226637 756.53 11.85 67.53 93.39 752.56 671.76 59.89 16.80 57.55 59.95 73.73 2.62 5959308.49 612106.26 N 70.29777289 W 149.09213604 847.68 14.84 70.40 91.15 841.24 760.44 80.91 24.29 77.20 80.93 72.53 3.36 5959316.28 612125.79 N 70.29779337 W 149.09197693 943.73 17.10 71.95 96.05 933.58 852.78 107.33 32.80 102.22 107.35 72.21 2.39 5959325.15 612150.68 N 70.29781659 W 149,09177437 1032.45 22.44 71.59 88.72 1017.04 936,24 137.32 42.19 130.71 137.35 72.11 6.02 5959334.97 612179.02 N 70.29784226 W 149.09154369 1124.58 27.48 70.53 92.13 1100,54 1019.74 176.19 54.84 167.45 176.21 71,87 5.49 5959348.16 612215.57 N 70.29787681 W 149.09124613 1216.78 31.59 70.47 92.20 1180.74 1099.94 221.63 70.01 210.29 221.64 71.59 4.46 5959363.97 612258.17 N 70.29791825 W 1.9929 1309.42 35,79 71.40 92.64 1257.80 1177.00 273.00 86.77 258.85 273,01 71.47 4.57 5959381 .45 612306.48 N 70.29796403 W 1 0605 1403.71 41.29 71.73 94.29 1331 .53 1250.73 331,72 105.33 314.57 331.73 71.49 5.84 5959400.84 612361.91 N 70.29801473 W 14. 05490 1499.77 46.27 71.44 96.06 1400.86 1320.06 398.16 126.32 377,61 398.18 71.50 5.19 5959422.77 612424.62 N 70.29807208 W 149.08954447 1593.72 50.76 70.27 93.95 1463.08 1382.28 468.52 149.42 444.07 468,53 71 .40 4.87 5959446.85 612490.72 N 70.29813518 W 149,08900631 1686.76 53.65 70.84 93.04 1520.09 1439.29 542.03 173.89 513.39 542.04 71.29 3,14 5959472.35 612559.66 N 70.29820201 W 149.08844497 1779.94 58.23 71.44 93.18 1572.27 1491.47 619.21 198.83 586.42 619,21 71.27 4.94 5959498.37 612632.31 N 70.29827012 W 149.08785357 1874.16 63.05 69.81 94.22 1618.45 1537,65 701,29 226,08 663.85 701.30 71.19 5,33 5959526.78 612709.32 N 70.29834457 W 149.08722656 1966.39 62.14 70.30 92.23 1660.90 1580.10 783.16 254.02 740.82 783.16 71.07 1.09 5959555.85 612785.86 N 70.29842086 W 149.08660331 2060.08 62.14 71.35 93.69 1704.69 1623.89 865.99 281.22 819.05 865.99 71.05 0,99 5959584.22 612863.67 N 70.29849516 W 149.08596980 2153.48 63.96 71.62 93.40 1747.01 1666.21 949.24 307,66 898.00 949.24 71.09 1,97 5959611.82 612942.20 N 70.29856735 W 149.08533052 2247.18 64.84 71.96 93.70 1787.50 1706.70 1033.73 334.06 978.27 1033.73 71.15 0.99 5959639.42 613022.06 N 70.29863946 W 149.08468052 2340.72 66.01 72.93 93.54 1826.40 1745.60 1118.77 359.72 1059.37 1118.78 71,24 1.57 5959666.28 613102.77 N 70.29870952 W 149.08402376 Version DO 3.1 RT (d031 rC546) 3.1 RT-SP3.03 W-215\W-215\W-215\W-215 Generated 10/23/20039:57 AM Page 1 of 4 I I Vertical I I Closure . I Comments Measured I Inclination I Azimuth Course TVD I Sub-Sea TVD I NS EW Closure I DLS I Northing Easting Latitude Longitude Depth Length Section Azimuth (II) (deg) (deg) (II) (II) (II) (II) (II) (II) (II) (deg) (deg/100 II) (flUS) (IIUS) 2431.34 65.10 72.46 90.62 1863.90 1783.10 1201.24 384.25 1138,13 1201.25 71,34 1.11 5959691.99 613181.15 N 70.29877652 W 149.08338595 2525.88 65.27 72.05 94.54 1903.58 1822.78 1287.03 410.41 1219.86 1287.05 71.41 0.43 5959719.35 613262.47 N 70.29884794 W 149.08272412 2620.25 65.30 72.91 94.37 1943.04 1862.24 1372.73 436.21 1301.61 1372.76 71.47 0,83 5959746.37 613343.82 N 70.29891840 W 149.08206212 2714.79 66.00 73.57 94.54 1982.02 1901.22 1458.79 461.05 1384.08 1458.85 71.58 0.98 5959772.43 613425.90 N 70.29898621 W 149.08139427 2808.02 65.41 73.38 93.23 2020.38 1939.58 1543.69 485.22 1465.54 1543.78 71.68 0.66 5959797.81 613506,99 N 70.29905219 W 149.08073457 2901.42 64.63 73.07 93.40 2059.82 1979,02 1628.29 509.65 1546.60 1628.41 71.76 0.89 5959823.45 613587.67 N 70.29911890 W 149.08007814 2994.96 63.71 73.85 93.54 2100.57 2019,77 1712.41 533,62 1627.31 1712.57 71.84 1.24 5959848.62 613668.00 N 70.29918434 W 149,07942455 3088.45 64.60 72.93 93.49 2141.33 2060.53 1796.48 557.68 1707.94 1796.68 71.92 1.30 5959873.87 613748.25 N 70.29925000 W 149.07877162 3181.69 64.26 72.94 93.24 2181.57 2100.77 1880.54 582,36 1788.34 1880.77 71.96 0.36 5959899.74 613828.27 N 70.29931738 W 149.07812048 3275.97 63.71 72.66 94.28 2222.92 2142.12 1965,23 607.41 1869.28 1965.49 72.00 0.64 5959926.00 613908.82 N 70.29938577 W 149.07746501 3367.59 64.74 71.58 91.62 2262.77 2181.97 2047.72 632.75 1947.79 2047.99 72,00 1.55 5959952,50 613986,94 N 70,29945493 W 149.07682915 3461.67 64.10 71.33 94.08 2303.39 2222.59 2132.58 659.73 2028.25 2132.85 71.98 0.72 5959980.68 614066,98 N 70.29952860 W 14.7761 3555.65 63.10 70.74 93.98 2345.17 2264.37 2216,75 687.09 2107.86 2217.01 71.95 1.20 5960009.22 614146.16 N 70.29960327 W 14 3289 3649.32 63.90 70.19 93.67 2386.97 2306.17 2300.58 715.12 2186.86 2300.81 71.89 1.00 5960038.42 614224.73 N 70.29967979 W 14 . 9308 3742.85 63.64 69.96 93.53 2428.31 2347.51 2384.46 743.71 2265.73 2384.67 71.83 0.35 5960068.18 614303.17 N 70.29975784 W 149.07425427 3837.01 63.00 69.55 94,16 2470.58 2389.78 2468.57 772.83 2344.67 2468,75 71.76 0.78 5960098.47 614381.65 N 70.29983730 W 149.07361497 3931.65 64.14 68.88 94.64 2512.71 2431.91 2553.28 802.90 2423.90 2553.42 71.67 1.36 5960129.72 614460.42 N 70.29991940 W 149.07297330 4023,93 63.26 68.17 92.28 2553.60 2472.80 2635.92 833.18 2500.88 2636.02 71.57 1.18 5960161.14 614536.94 N 70.30000206 W 149.07234980 4116.77 64.73 68.61 92.84 2594.30 2513.50 2719.27 863.91 2578.46 2719,34 71.48 1.64 5960193.02 614614.04 N 70.30008593 W 149.07172152 4211.42 64.29 68.61 94.65 2635.03 2554.23 2804.63 895.07 2658.01 2804.67 71.39 0.46 5960225.36 614693.11 N 70.30017099 W 149.07107721 4241.54 64.18 68.85 30,12 2648.13 2567.33 2831.73 904.91 2683.29 2831,77 71.36 0.81 5960235.58 614718.23 N 70.30019784 W 149.07087248 4273.03 63,83 68.81 31.49 2661.93 2581.13 2860.01 915.13 2709.68 2860.04 71.34 1.12 5960246.19 614744.47 N 70.30022574 W 149.07065871 4286.08 63.65 68.41 13.05 2667.70 2586.90 2871.70 919.40 2720.58 2871.73 71.33 3.08 5960250.62 614755.30 N 70.30023739 W 149.07057045 4417.34 62.20 69.04 131.26 2727.44 2646.64 2988.48 961.81 2829.48 2988.49 71.23 1.18 5960294.64 614863.55 N 70.30035314 W 149.06968840 4510.68 62.40 69.55 93.34 2770.83 2690.03 3071.08 991.03 2906.79 3071.08 71.17 0,53 5960325.01 614940.41 N 70.30043288 W 149.06906228 4604.25 63.68 69.49 93.57 2813.25 2732.45 3154.45 1020.21 2984.92 3154.45 71.13 1.37 5960355.35 615018.08 N 70.30051252 W 149.06842949 4697,61 63.45 69.52 93.36 2854.82 2774.02 3238.02 1049.48 3063.22 3238.02 71.09 0.25 5960385.78 615095.94 N 70.30059240 W 149.06779525 4790.33 62.98 69.88 92.72 2896.60 2815.80 3320.76 1078.20 3140.85 3320.76 71.05 0.61 5960415.65 615173.12 N 70.30067076 W 149.06716648 4883.86 63.71 68.88 93.53 2938.56 2857.76 3404.31 1107.64 3219.08 3404.32 71.01 1.23 5960446.25 615250.90 N 70.30075109 W 149.06653283 4977.86 62.81 68.35 94.00 2980.85 2900.05 3488.18 1138.24 3297,25 3488.19 70.95 1.08 5960478.01 615328.60 N 70.30083462 W 149.06589970 5070.70 63.20 69.08 92.84 3022.99 2942.19 3570.84 1168.27 3374.33 3570.85 70.90 0.82 5960509.19 615405.22 N 70,30091656 W 1.7536 5164.58 64.09 69.06 93.88 3064.67 2983.87 3654,91 1198.32 3452.90 3654,93 70.86 0.95 5960540.40 615483.32 N 70.30099856 W 1 3895 5256.68 63.57 68.24 92.10 3105.29 3024.49 3737.49 1228.41 3529.89 3737,53 70.81 0.98 5960571.64 615559.84 N 70.30108067 W 149. 401538 5350.27 62.17 68.86 93.59 3147.97 3067.17 3820.70 1258.88 3607.41 3820.76 70.76 1.61 5960603.25 615636.89 N 70.30116379 W 149.06338746 5444.14 62.17 68.26 93.87 3191.79 3110.99 3903.63 1289.22 3684.68 3903.71 70.72 0.57 5960634.73 615713.69 N 70.30124658 W 149.06276159 5537.82 63.49 68.33 93.68 3234,57 3153.77 3986.88 1320.04 3762.11 3986.98 70.67 1.41 5960666.70 615790.65 N 70,30133068 W 149,06213438 5631.67 63.62 69.58 93,85 3276.36 3195.56 4070.85 1350.21 3840.53 4070.97 70.63 1.20 5960698.04 615868,61 N 70.30141300 W 149.06149914 5725.07 63.10 69.65 93.40 3318.24 3237.44 4154.30 1379.29 3918.79 4154.44 70.61 0.56 5960728.28 615946.42 N 70,30149233 W 149.06086526 5819.24 63.93 69.50 94.17 3360,24 3279.44 4238.56 1408.71 3997.78 4238.71 70.59 0.89 5960758.87 616024.95 N 70.30157258 W 149.06022545 5912,84 64.40 70.00 93.60 3401.03 3320.23 4322.78 1437.87 4076.81 4322,95 70.57 0.70 5960789.20 616103.54 N 70.30165212 W 149.05958522 6005.85 64,09 70.41 93.01 3441 .44 3360,64 4406.54 1466.24 4155.63 4406.71 70.57 0.52 5960818.74 616181.92 N 70.30172950 W 149.05894676 6098.74 63.42 70.19 92.89 3482.52 3401.72 4489.85 1494.32 4234,07 4490.03 70.56 0.75 5960847.99 616259.92 N 70.30180611 W 149.05831139 6192.26 64.25 70.63 93.52 3523.76 3442.96 4573.78 1522.46 4313.15 4573.96 70.56 0.98 5960877.30 616338.56 N 70.30188287 W 149,05767083 6285,85 63.70 70.75 93.59 3564.82 3484.02 4657.88 1550.27 4392.52 4658.06 70.56 0.60 5960906.29 616417.50 N 70.30195872 W 149.05702791 Version DO 3.1RT (d031rt_546) 3.1 RT-SP3.03 W-215\W-215\W-215\W-215 Generated 10/23/2003 9:57 AM Page 2 of 4 Comments Measured I Inclination I Azimuth I Course I TVD I Sub-Sea TVD I Vertical I NS EW Closure I Closure I DLS I Northing Easting Latitude Longitude Depth Length Section Azimuth (II) (deg) (deg) (II) (II) (II) (II) (II) (II) (II) (deg) (deg/100 II) (IIUS) (IIUS) 6378.99 62.85 70.58 93.14 3606.71 3525.91 4741.07 1577.82 4471.01 4741.25 70.56 0.93 5960935.00 616495.57 N 70.30203383 W 149.05639204 6473.32 62.21 71.08 94.33 3650.22 3569.42 4824.76 1605.30 4550.07 4824.95 70.57 0.83 5960963.65 616574.20 N 70.30210879 W 149.05575167 6566.61 62.63 70.58 93.29 3693,41 3612.61 4907,45 1632,45 4628.17 4907.63 70.57 0.65 5960991.97 616651.88 N 70.30218284 W 149.05511899 6660.39 63,49 70.98 93,78 3735.90 3655.10 4991.05 1659.97 4707,11 4991.23 70.57 0,99 5961020.66 616730,40 N 70.30225789 W 149.05447950 6754.47 64.51 70.74 94.08 3777.14 3696.34 5075.60 1687.70 4787.00 5075.79 70.58 1.11 5961049.57 616809.85 N 70.30233349 W 149.05383239 6847.66 63.71 70.97 93,19 3817.83 3737.03 5159,44 1715.19 4866,19 5159.63 70.58 0.89 5961078.24 616888.63 N 70.30240847 W 149.05319082 6942.02 63.01 71,51 94.36 3860.14 3779.34 5243.78 1742,32 4946.06 5243.96 70.59 0.90 5961106.55 616968.07 N 70.30248243 W 149.05254389 7035.57 63.52 72.29 93.55 3902.23 3821.43 5327.32 1768.27 5025,47 5327.49 70.61 0.92 5961133.68 617047.08 N 70.30255320 W 149.05190057 7129.26 64.09 71.04 93.69 3943.59 3862.79 5411.38 1794,72 5105.27 5411.54 70.63 1.34 5961161.31 617126.46 N 70.30262530 W 149.05125415 7222.11 64,06 70.27 92.85 3984.18 3903.38 5494.88 1822,38 5184.06 5495.05 70.63 0.75 5961190.15 617204.83 N 70.30270072 W 149,05061586 7316,35 63.42 70,49 94.24 4025.88 3945.08 5579.39 1850.76 5263,66 5579.56 70,63 0.71 5961219,70 617284.00 N 70.30277810 W 149,04997096 7408.90 64,13 70.27 92.55 4066.77 3985.97 5662,41 1878.64 5341.87 5662.58 70.62 0,80 5961248.74 617361.77 N 70.30285411 W 14.3743 7502,64 63.26 70.29 93,74 4108.31 4027.51 5746.43 1906.99 5420.97 5746.61 70.62 0.93 5961278.27 617440.43 N 70.30293141 W 14 . 9659 7596.01 63.68 70.33 93.37 4150.02 4069.22 5829.96 1935.14 5499,62 5830.15 70.61 0,45 5961307.58 617518.65 N 70.30300815 W 149.04805939 7689.19 63.84 70.26 93.18 4191.22 4110.42 5913.53 1963.32 5578.31 5913.72 70.61 0.18 5961336.93 617596.90 N 70.30308498 W 149.04742195 7782.51 63.36 70.34 93.32 4232.71 4151.91 5997,11 1991.50 5657.00 5997.31 70.61 0.52 5961366.28 617675.16 N 70.30316180 W 149.04678441 7876.44 63.94 71.37 93,93 4274,40 4193.60 6081.28 2019.10 5736.52 6081,48 70.61 1.16 5961395.06 617754.24 N 70.30323704 W 149.04614023 7969.74 63.90 71.03 93.30 4315,42 4234.62 6165.08 2046.11 5815.85 6165.27 70.62 0.33 5961423.24 617833.15 N 70.30331065 W 149.04549755 8062.83 63.14 70.91 93.09 4356.93 4276.13 6248,40 2073.27 5894.61 6248.60 70.62 0.82 5961451.58 617911.50 N 70.30338470 W 149.04485940 8156,44 63.43 71.36 93,61 4399.01 4318.21 6332.02 2100.31 5973.74 6332.21 70.63 0.53 5961479.79 617990.21 N 70.30345839 W 149,04421836 8250.01 62.98 71.78 93.57 4441.19 4360.39 6415.54 2126.72 6052.98 6415.72 70.64 0.63 5961507.37 618069.04 N 70.30353036 W 149.04357640 8342,86 62.66 71.26 92,85 4483.60 4402.80 6498.14 2152.90 6131.32 6498.31 70.65 0.61 5961534.72 618146.97 N 70.30360171 W 149.04294174 8435.52 63.81 72.06 92,66 4525.33 4444.53 6580,86 2178.93 6209.85 6581.03 70.66 1,46 5961561.91 618225.10 N 70.30367264 W 149.04230552 8529.32 64.60 72.50 93.80 4566.15 4485.35 6665.29 2204.63 6290,29 6665,44 70.69 0.94 5961588,81 618305.14 N 70.30374268 W 149.04165378 8622.41 64.04 72.42 93.09 4606,49 4525.69 6749.16 2229.91 6370.29 6749.30 70.71 0.61 5961615,28 618384.75 N 70.30381156 W 149.04100569 8714.91 64.04 72.02 92.50 4646.98 4566,18 6832.31 2255.31 6449,48 6832,44 70,73 0.39 5961641.85 618463.54 N 70.30388076 W 149.04036408 8808,18 63.68 72.16 93,27 4688.07 4607.27 6916.03 2281.06 6529.15 6916,14 70.74 0,41 5961668.78 618542.82 N 70.30395091 W 149.03971859 8901.86 63.30 72,02 93.68 4729.88 4649.08 6999.85 2306.84 6608.92 6999.95 70.76 0.43 5961695.74 618622.19 N 70.30402115 W 149.03907232 8995.21 63.62 72.19 93.35 4771.60 4690.80 7083.35 2332.50 6688.39 7083,44 70.77 0.38 5961722.59 618701.26 N 70.30409106 W 149.03842843 9088.31 63.96 72.00 93.10 4812.71 4731.91 7166.86 2358.18 6767.88 7166.95 70.79 0,41 5961749,45 618780.34 N 70.30416102 W 149.03778447 9182.39 64.00 71.90 94.08 4853.99 4773.19 7251,40 2384.37 6848.26 7251.47 70.80 0.10 5961776.83 618860.32 N 70.30423239 W 1.13320 9276.05 62.53 72,48 93.66 4896.12 4815,32 7335.02 2409.96 6927.89 7335.09 70.82 1.66 5961803.60 618939.56 N 70.30430209 W 149. 648799 9369.17 60.75 72.91 93.12 4940.35 4859.55 7416.93 2434,34 7006.12 7416.99 70.84 1.95 5961829.14 619017,41 N 70.30436848 W 149.03585416 9461.91 59.06 72.77 92.74 4986.85 4906.05 7497.13 2458.01 7082.79 7497.18 70.86 1.83 5961853.95 619093.70 N 70.30443296 W 149.03523302 9555.55 57,48 71.69 93.64 5036.10 4955.30 7576.75 2482.31 7158.63 7576.80 70,88 1.95 5961879.38 619169,17 N 70.30449915 W 149.03461853 9649.60 57.01 71.74 94.05 5086.98 5006.18 7655.84 2507.12 7233.73 7655.88 70.88 0.50 5961905.31 619243.89 N 70,30456674 W 149.03401003 9742.70 56.92 72.69 93.10 5137.74 5056.94 ' 7733.87 2530,96 7308.05 7733.91 70.90 0.86 5961930.25 619317.83 N 70.30463168 W 149.03340789 9836.11 57.06 72.85 93,41 5188.63 5107.83 7812,17 2554.17 7382.87 7812.20 70.92 0.21 5961954.56 619392.29 N 70.30469486 W 149.03280170 9929.78 57.56 73.33 93.67 5239.22 5158.42 7890.95 2577.09 7458.29 7890.98 70.94 0.69 5961978.61 619467.36 N 70.30475730 W 149.03219059 10022.71 57,41 73.85 92.93 5289.17 5208.37 7969.24 2599.23 7533,46 7969.26 70.96 0.50 5962001.87 619542.18 N 70.30481757 W 149.03158154 10117.05 57.29 72.83 94.34 5340.07 5259.27 8048.61 2622.00 7609.56 8048.62 70.99 0.92 5962025.77 619617.92 N 70.30487957 W 149.03096497 10210.86 56.98 72.29 93.81 5390.97 5310.17 8127.38 2645.62 7684.73 8127.38 71.00 0,59 5962050.50 619692.73 N 70.30494388 W 149.03035588 10304.67 56,47 73.56 93.81 5442,45 5361.65 8205.76 2668.65 7759.70 8205.77 71.02 1.26 5962074.64 619767.34 N 70.30500659 W 149,02974844 Version DO 3.1RT (do31 rL546) 3.1 RT-SP3.03 W-215\W-215\W-215\W-215 Generated 10/23/2003 9:57 AM Page 3 of 4 Comments Measured I Inclination I Azimuth I Course I TVD I Sub-Sea TVD I Vertical I NS EW Closure I Closure I DLS I Northing Easting Latitude LOngitudel Depth Length Section Azimuth (II) (deg) (deg) (II) (II) (II) (II) (II) (II) (II) (deg) (degNOO II) (IIUS) (flUS) 10397.80 56.13 73.04 93.13 5494.12 5413.32 8283.19 2690.91 7833.91 8283.19 71.04 0.59 5962098.01 619841.21 N 70.30506720 W 149.02914714 10490.59 55.79 72.88 92.79 5546.06 5465.26 8360.03 2713.44 7907.43 8360.03 71.06 0.39 5962121.63 619914.37 N 70.30512854 W 149.02855147 10522.48 55.77 72.40 31.89 5563.99 5483.19 8386.39 2721.31 7932.59 8386.39 71.07 1.25 5962129.87 619939.42 N 70.30514996 W 149,02834755 10594.00 55.77 72.40 71.52 5604.22 5523.42 8445.51 2739.19 7988.96 8445.51 71.07 0.00 5962148.59 619995.50 N 70.30519865 W 149.02789084 Leqal Description: Northinq (Y) [nUS] Eastinq IX) [nus] Surface: 4313 FSL 1186 FEL S21 T11N R12E UM 5959290,84 612048.97 BHL: 1768 FSL 3751 FEL S14 T11N R12E UM 5962148.59 619995.50 . . Version DO 3.1 RT ( do31 rL546 ) 3.1 RT-SP3.03 W-215\W-215\W-215\W-215 Generated 10/23/2003 9:57 AM Page 4 of 4 SCBLUMBERGER Survey report Client...... .......... ...: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: Polaris Well. . . . . . . . . . . . . . . . . . . . .: W-215i PB1 API number. ....... .......: 50-029-23172-70 Engineer.. .......... .....: St. Amour Rig. . . . . . . . . . . . . . . . . . . . . .: Nabors 9ES STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS... ........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum.. ........: Mean Sea Level Depth reference... .......: Driller's Pipe Tally GL above permanent.......: 52.30 ft KB above permanent. .... ..: N/A (Topdrive) DF above permanent.... ...: 80.80 ft ----- Vertical section origin---------------- Latitude (+N/S-)...... ...: 0.00 ft Departure (+E/W-) ..... ...: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from rotary table to target: 70.75 degrees 12-Sep-2003 13:46:20 Spud date.... ..... .... ...: Last survey date.........: Total accepted surveys...: MD ot first survey... ....: MD of last survey.... ....: Page 1 of 2 9-September-2003 12-Sep-03 15 0.00 ft 1372.00 ft . ----- Geomagnetic data ---------------------- Magnetic model..... ......: BGGM version 2002 Magnetic date...... ......: 09-Sep-2003 Magnetic field strength..: 1150.55 BCNT Magnetic dec (+E/W-) .....: 25.52 degrees Magnetic dip.... .... .....: 80.78 degrees ----- MWD survey Reference Reference G... ..... ......: Reference B... ..... ......: Reference Dip. .... .......: Tolerance of G.... ..... ..: Tolerance of B.... ..... ..: Tolerance of Dip. ..... ...: Criteria --------- 1002.68 mGal 1151.00 BCNT 80.81 degrees (+/-) 2.50 mGal (+/-) 6.00 BCNT (+/-) 0.45 degrees . ----- Corrections --------------------------- Magnetic dec (+E/W-).. ...: 25.34 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) ....: 25.34 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type ...: I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction SCHLUMBERGER Survey Report 12-Sep-2003 13:46:20 Page 2 of 2 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ Seg Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 198.26 0.48 77.98 198.26 198.26 0.82 0.17 0.81 0.83 77.98 0.24 MWD IFR MSA - 3 291.55 2.79 81. 56 93.29 291. 50 3.44 0.59 3.44 3.49 80.31 2.48 MWD IFR MSA - 4 384.88 4.37 79.19 93.33 384.65 9.19 1.59 9.18 9.32 80.19 1. 70 MWD IFR MSA - 5 477.17 6.11 78.09 92.29 476.55 17.54 3.26 17.44 17.74 79.41 1. 89 MWD IFR MSA 6 570.26 7.75 72.69 93.09 568.96 28.73 6.15 28.28 28.94 77.73 1. 89 MWD IFR MSA . - 7 663.14 9.46 70.47 92.88 660.79 42.62 10.57 41. 45 42.78 75.70 1.88 MWD IFR MSA - 8 756.53 11.85 67.53 93.39 752.56 59.87 16.80 57.55 59.95 73.73 2.62 MWD IFR MSA - 9 847.68 14.84 70.40 91.15 841.24 80.89 24.29 77 .20 80.93 72.53 3.36 MWD IFR MSA - 10 940.53 18.16 71.59 92.85 930.26 107.26 32.85 102.14 107.29 72 .17 3.59 MWD IFR MSA 11 1033.56 22.91 71.81 93.03 1017.35 139.88 43.09 133.11 139.91 72.06 5.11 MWD IFR MSA - 12 1127.35 26.13 72.37 93.79 1102.67 178.79 55.05 170.15 178.83 72.07 3.44 MWD IFR MSA - 13 1220.85 28.25 71.58 93.50 1185.83 221. 50 68.28 210.77 221. 55 72.05 2.30 MWD IFR MSA - 14 1314.24 32.43 70.19 93.39 1266.42 268.66 83.75 255.32 268.71 71. 84 4.54 MWD IFR MSA 15 1372.00 32.43 70.19 57.76 1315.17 299.63 94.25 284.46 299.67 71.67 0.00 Projected [(c)2003 IDEAL ID8_1C_01J . SCHLUMBERGER Survey report Client.. ..... ....... .....: BP Exploration (Alaska) Inc. Field. ............... ....: Polaris Well. . . . . . . . . . . . . . . . . . . . .: W-215i API number... ....... .....: 50-029-23172-00 Engineer.. ... ........ ....: St. Amour Rig. . . . . . . . . . . . . . . . . . . . . .: Nabors 9ES STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions... ..: Minimum curvature Method for DLS.... ... ....: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..... .....: Mean Sea Level Depth reference....... ...: Driller's Pipe Tally GL above permanent.. .....: 52.30 ft KB above permanent.. .....: N/A - Top Drive DF above permanent.. .....: 80.80 ft ----- Vertical section origin---------------- Latitude (+N/S-) .........: 0.00 ft Departure (+E/W-).. ... ...: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).. .... ...: -999.25 ft Departure (+E/W-). .......: -999.25 ft Azimuth from rotary table to target: 70.75 degrees [(c)2003 IDEAL ID8_1C_01] 17-Sep-2003 06:51:15 Spud date.. ......... .....: Last survey date.... .....: Total accepted surveys...: MD of first survey.......: MD of last survey........: . I Page 1 of 5 9-September-2003 17-September-2003 114 0.00 ft 10594.00 ft . I ----- Geomagnetic data ---------------------- Magnetic model..... ......: BGGM version 2002 Magnetic date. ..... ......: 09-Sep-2003 Magnetic field strength..: 1150.55 HCNT Magnetic dec (+E/W-). ....: 25.52 degrees Magnetic dip.. ...........: 80.78 degrees ----- MWD survey Reference Reference G... .... .......: Reference H. ... ...... ....: Reference Dip........ ....: Tolerance of G...... .,. ..: Tolerance of H...... .....: Tolerance of Dip.. .......: Criteria --------- 1002.68 mGal 1150.55 HCNT 80.78 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees . ----- Corrections --------------------------- Magnetic dec (+E/W-) .....: 25.52 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) ....: 25.52 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type...: I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction SCHLUMBERGER Survey Report 24-Sep-2003 11:38:50 Page 2 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg: -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 198.26 0.48 77.98 198.26 198.26 0.82 0.17 0.81 0.83 77.98 0.24 MWD IFR MSA 3 291. 55 2.79 81. 56 93.29 291. 50 3.44 0.59 3.44 3.49 80.31 2.48 MWD IFR MSA 4 384.88 4.37 79.19 93.33 384.65 9.19 1. 59 9.18 9.32 80.19 1. 70 MWD IFR MSA 5 477.17 6.11 78.09 92.29 476.55 17.54 3.26 17.44 17.74 79.41 1. 89 MWD IFR MSA 6 570.26 7.75 72.69 93.09 568.96 28.73 6.15 28.28 28.94 77.73 1. 89 MWD IFR MSA . 7 663.14 9.46 70.47 92.88 660.79 42.62 10.57 41. 45 42.78 75.70 1.88 MWD IFR MSA 8 756.53 11.85 67.53 93.39 752.56 59.87 16.80 57.55 59.95 73.73 2.62 MWD IFR MSA - 9 847.68 14.84 70.40 91.15 841. 24 80.89 24.29 77.20 80.93 72.53 3.36 MWD IFR MSA - 10 943.73 17.10 71.95 96.05 933.58 107.32 32.80 102.22 107.35 72 .21 2.39 MWD IFR MSA 11 1032.45 22.44 71.59 88.72 1017.04 137.31 42.19 130.71 137.35 72.11 6.02 MWD IFR MSA - 12 1124.58 27.48 70.53 92.13 1100.54 176.17 54.84 167.45 176.21 71.87 5.49 MWD IFR MSA - 13 1216.78 31. 59 70.47 92.20 1180.74 221. 61 70.01 210.29 221. 64 71. 59 4.46 MWD IFR MSA 14 1309.42 35.79 71. 40 92.64 1257.80 272.99 86.77 258.85 273.01 71.47 4.57 MWD IFR MSA 15 1403.71 41. 29 71.73 94.29 1331.53 331. 71 105.33 314.57 331. 73 71.49 5.84 MWD IFR MSA 16 1499.77 46.27 71.44 96.06 1400.86 398.14 126.32 377.61 398.18 71.50 5.19 MWD IFR MSA - 17 1593.72 50.76 70.27 93.95 1463.08 468.50 149.42 444.07 468.53 71.40 4.87 MWD IFR MSA - 18 1686.76 53.65 70.84 93.04 1520.09 542.01 173.89 513.39 542.04 71. 29 3.14 MWD IFR MSA - 19 1779.94 58.23 71. 44 93.18 1572.27 619.19 198.83 586.42 619.21 71. 27 4.94 MWD IFR MSA - 20 1874.16 63.05 69.81 94.22 1618.45 701. 28 226.08 663.85 701. 30 71.19 5.33 MWD IFR MSA 21 1966.39 62.14 70.30 92.23 1660.90 783.15 254.02 740.82 783.16 71. 07 1. 09 MWD IFR MSA . 22 2060.08 62.14 71.35 93.69 1704.69 865.98 281. 22 819.05 865.99 71.05 0.99 MWD IFR MSA 23 2153.48 63.96 71.62 93.40 1747.01 949.22 307.66 898.00 949.24 71.09 1. 97 MWD IFR MSA 24 2247.18 64.84 71.96 93.70 1787.50 1033.71 334.06 978.27 1033.73 71.15 0.99 MWD IFR MSA 25 2340.72 66.01 72.93 93.54 1826.40 1118.74 359.72 1059.37 1118.78 71.24 1. 57 MWD IFR MSA 26 2431. 34 65.10 72.46 90.62 1863.90 1201.18 384.25 1138.13 1201. 25 71. 34 1.11 MWD IFR MSA - 27 2525.88 65.27 72.05 94.54 1903.58 1286.97 410.41 1219.86 1287.05 71.41 0.43 MWD IFR MSA 28 2620.25 65.30 72.91 94.37 1943.04 1372.65 436.21 1301. 61 1372.76 71.47 0.83 MWD IFR MSA 29 2714.79 66.00 73 .57 94.54 1982.02 1458.70 461.05 1384.08 1458.85 71.58 0.98 MWD IFR MSA 30 2808.02 65.41 73.38 93.23 2020.38 1543.58 485.22 1465.54 1543.78 71.68 0.66 MWD IFR MSA [(c)2003 IDEAL ID8_1C_01] SCHLUMBERGER Survey Report 24-Sep-2003 11:38:50 Page 3 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (de g) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 2901. 42 64.63 73.07 93.40 2059.82 1628.16 509.65 1546.60 1628.41 71.76 0.89 MWD IFR MSA - 32 2994.96 63.71 73.85 93.54 2100.57 1712.26 533.62 1627.31 1712.57 71. 84 1.24 MWD IFR MSA - 33 3088.45 64.60 72.93 93.49 2141.33 1796.30 557.68 1707.94 1796.68 71. 92 1.30 MWD IFR MSA - 34 3181.69 64.26 72.94 93.24 2181. 57 1880.35 582.36 1788.34 1880.77 71.96 0.36 MWD IFR MSA - 35 3275.97 63.71 72.66 94.28 2222.92 1965.02 607.41 1869.28 1965.49 72.00 0.64 MWD IFR MSA 36 3367.59 64.74 71.58 91. 62 2262.77 2047.50 632.75 1947.79 2047.99 72.00 1.55 MWD IFR MSA . - 37 3461.67 64.10 71. 33 94.08 2303.39 2132.35 659.73 2028.25 2132.85 71.98 0.72 MWD IFR MSA - 38 3555.65 63.10 70.74 93.98 2345.17 2216.53 687.09 2107.86 2217.01 71.95 1.20 MWD IFR MSA - 39 3649.32 63.90 70.19 93.67 2386.97 2300.36 715.12 2186.86 2300.81 71.89 1. 00 MWD IFR MSA - 40 3742.85 63.64 69.96 93.53 2428.31 2384.25 743.71 2265.73 2384.67 71.83 0.35 MWD IFR MSA 41 3837.01 63.00 69.55 94.16 2470.58 2468.37 772 . 83 2344.67 2468.75 71.76 0.78 MWD IFR MSA - 42 3931.65 64.14 68.88 94.64 2512.71 2553.09 802.90 2423.90 2553.42 71.67 1. 36 MWD IFR MSA 43 4023.93 63.26 68.17 92.28 2553.60 2635.75 833.18 2500.88 2636.02 71. 57 1.18 MWD IFR MSA 44 4116.77 64.73 68.61 92.84 2594.30 2719.12 863.91 2578.46 2719.34 71.48 1. 64 MWD IFR MSA 45 4211.42 64.29 68.61 94.65 2635.03 2804.49 895.07 2658.01 2804.67 71.39 0.46 MWD IFR MSA 46 4241.54 64.18 68.85 30.12 2648.13 2831. 60 904.91 2683.29 2831.77 71.36 0.81 MWD IFR MSA 47 4273.03 63.83 68.81 31.49 2661.93 2859.89 915.13 2709.68 2860.04 71. 34 1.12 MWD IFR MSA 48 4286.08 63.65 68.41 13.05 2667.70 2871.59 919.40 2720.58 2871.73 71.33 3.08 MWD IFR MSA 49 4417.34 62.20 69.04 131.26 2727.44 2988.38 961. 81 2829.48 2988.49 71. 23 1.18 MWD IFR MSA - 50 4510.68 62.40 69.55 93.34 2770.83 3071.00 991.03 2906.79 3071.08 71.17 0.53 MWD IFR MSA 51 4604.25 63.68 69.49 93.57 2813.25 3154.38 1020.21 2984.92 3154.45 71.13 1.37 MWD IFR MSA . 52 4697.61 63.45 69.52 93.36 2854.82 3237.96 1049.48 3063.22 3238.01 71. 09 0.25 MWD IFR MSA - 53 4790.33 62.98 69.88 92.72 2896.60 3320.72 1078.20 3140.85 3320.76 71. 05 0.61 MWD IFR MSA 54 4883.86 63.71 68.88 93.53 2938.56 3404.28 1107.64 3219.08 3404.32 71. 01 1.23 MWD IFR MSA 55 4977 . 86 62.81 68.35 94.00 2980.85 3488.17 1138.24 3297.25 3488.19 70.95 1. 08 MWD IFR MSA 56 5070.70 63.20 69.08 92.84 3023.00 3570.84 1168.27 3374.33 3570.85 70.90 0.82 MWD IFR MSA - 57 5164.58 64.09 69.06 93.88 3064.67 3654.92 1198.32 3452.90 3654.93 70.86 0.95 MWD IFR MSA - 58 5256.68 63.57 68.24 92.10 3105.29 3737.53 1228.42 3529.89 3737.53 70.81 0.98 MWD IFR MSA 59 5350.27 62.17 68.86 93.59 3147.97 3820.76 1258.88 3607.41 3820.76 70.76 1.61 MWD IFR MSA 60 5444.14 62.17 68.26 93.87 3191.79 3903.71 1289.22 3684.68 3903.71 70.72 0.57 MWD IFR MSA [(c)2003 IDEAL ID8_1C_01J SCHLUMBERGER Survey Report 24-Sep-2003 11:38:50 Page 4 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg: -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 5537.82 63.49 68.33 93.68 3234.57 3986.97 1320.04 3762.11 3986.98 70.67 1.41 MWD IFR MSA 62 5631. 67 63.62 69.58 93.85 3276.36 4070.96 1350.21 3840.53 4070.97 70.63 1.20 MWD IFR MSA 63 5725.07 63.10 69.65 93.40 3318.24 4154.43 1379.29 3918.79 4154.44 70.61 0.56 MWD IFR MSA 64 5819.24 63.93 69.50 94.17 3360.24 4238.69 1408.71 3997.78 4238.71 70.59 0.89 MWD IFR MSA 65 5912.84 64.40 70.00 93.60 3401.03 4322.93 1437.87 4076.81 4322.95 70.57 0.70 MWD IFR MSA 66 6005.85 64.09 70.41 93.01 3441. 44 4406.69 1466.24 4155.63 4406.71 70.57 0.52 MWD IFR MSA . 67 6098.74 63.42 70.19 92.89 3482.52 4490.00 1494.32 4234.07 4490.03 70.56 0.75 MWD IFR MSA 68 6192.26 64.25 70.63 93.52 3523.76 4573.94 1522.46 4313.15 4573.96 70.56 0.98 MWD IFR MSA 69 6285.85 63.70 70.75 93.59 3564.82 4658.04 1550.27 4392.52 4658.06 70.56 0.60 MWD IFR MSA 70 6378.99 62.85 70.58 93.14 3606.71 4741.23 1577.82 4471.01 4741. 25 70.56 0.93 MWD IFR MSA 71 6473.32 62.21 71. 08 94.33 3650.22 4824.92 1605.30 4550.07 4824.94 70.57 0.83 MWD IFR MSA 72 6566.61 62.63 70.58 93.29 3693.41 4907.61 1632.45 4628.17 4907.63 70.57 0.65 MWD IFR MSA - 73 6660.39 63.49 70.98 93.78 3735.90 4991. 21 1659.97 4707.11 4991.23 70.57 0.99 MWD IFR MSA 74 6754.47 64.51 70.74 94.08 3777.14 5075.77 1687.70 4787.00 5075.79 70.58 1.11 MWD IFR MSA 75 6847.66 63.71 70.97 93.19 3817.83 5159.60 1715.19 4866.19 5159.63 70.58 0.89 MWD IFR MSA - 76 6942.02 63.01 71. 51 94.36 3860.14 5243.94 1742.32 4946.06 5243.96 70.59 0.90 MWD IFR MSA - 77 7035.57 63.52 72 .29 93.55 3902.23 5327.47 1768.27 5025.47 5327.49 70.61 0.92 MWD IFR MSA - 78 7129.26 64.09 71.04 93.69 3943.59 5411. 53 1794.72 5105.27 5411.54 70.63 1.34 MWD IFR MSA - 79 7222.11 64.06 70.27 92.85 3984.18 5495.03 1822.38 5184.06 5495.05 70.63 0.75 MWD IFR MSA 80 7316.35 63.42 70.49 94.24 4025.88 5579.55 1850.76 5263.66 5579.56 70.63 0.71 MWD IFR MSA 81 7408.90 64.13 70.27 92.55 4066.77 5662.57 1878.64 5341. 87 5662.58 70.62 0.80 MWD IFR MSA . - 82 7502.64 63.26 70.29 93.74 4108.31 5746.60 1906.99 5420.97 5746.61 70.62 0.93 MWD IFR MSA - 83 7596.01 63.68 70.33 93.37 4150.02 5830.13 1935.14 5499.62 5830.15 70.61 0.45 MWD IFR MSA - 84 7689.19 63.84 70.26 93.18 4191. 22 5913.71 1963.32 5578.31 5913.72 70.61 0.18 MWD IFR MSA - 85 7782.51 63.36 70.34 93.32 4232.71 5997.29 1991. 50 5657.00 5997.31 70.61 0.52 MWD IFR MSA 86 7876.44 63.94 71.37 93.93 4274.40 6081.46 2019.10 5736.52 6081. 48 70.61 1.16 MWD IFR MSA 87 7969.74 63.90 71.03 93.30 4315.42 6165.26 2046.10 5815.85 6165.27 70.62 0.33 MWD IFR MSA 88 8062.83 63.14 70.91 93.09 4356.93 6248.58 2073.27 5894.62 6248.60 70.62 0.82 MWD IFR MSA - 89 8156.44 63.43 71.36 93.61 4399.01 6332.20 2100.31 5973.74 6332.21 70.63 0.53 MWD IFR MSA - 90 8250.01 62.98 71.78 93.57 4441.19 6415.71 2126.72 6052.98 6415.72 70.64 0.63 MWD IFR MSA [(c)2003 IDEAL ID8_1C_01] SCHLUMBERGER Survey Report 24-Sep-2003 11:38:50 Page 5 of 5 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (degJ --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 91 8342.86 62.66 71. 26 92.85 4483.60 6498.30 2152.90 6131.32 6498.31 70.65 0.61 MWD IFR MSA - 92 8435.52 63.81 72.06 92.66 4525.33 6581.02 2178.92 6209.85 6581. 03 70.66 1.46 MWD IFR MSA - 93 8529.32 64.60 72 .50 93.80 4566.15 6665.44 2204.63 6290.29 6665.45 70.69 0.94 MWD IFR MSA 94 8622.41 64.04 72 .42 93.09 4606.49 6749.30 2229.91 6370.29 6749.30 70.71 0.61 MWD IFR MSA - 95 8714.91 64.04 72.02 92.50 4646.98 6832.44 2255.31 6449.48 6832.44 70.73 0.39 MWD IFR MSA 96 8808.18 63.68 72 .16 93.27 4688.07 6916.15 2281. 06 6529.15 6916.15 70.74 0.41 MWD IFR MSA . 97 8901. 86 63.30 72.02 93.68 4729.88 6999.95 2306.84 6608.92 6999.95 70.76 0.43 MWD IFR MSA 98 8995.21 63.62 72.19 93.35 4771.59 7083.44 2332.50 6688.39 7083.44 70.77 0.38 MWD IFR MSA 99 9088.31 63.96 72.00 93.10 4812.71 7166.95 2358.18 6767.88 7166.95 70.79 0.41 MWD IFR MSA - 100 9182.39 64.00 71.90 94.08 4853.98 7251. 47 2384.37 6848.26 7251. 47 70.80 0.10 MWD IFR MSA 101 9276.05 62.53 72.48 93.66 4896.12 7335.09 2409.96 6927.89 7335.09 70.82 1.66 MWD IFR MSA 102 9369.17 60.75 72.91 93.12 4940.35 7416.98 2434.34 7006.12 7416.99 70.84 1. 95 MWD IFR MSA 103 9461. 91 59.06 72.77 92.74 4986.85 7497.16 2458.01 7082.79 7497.18 70.86 1. 83 MWD IFR MSA 104 9555.55 57.48 71.69 93.64 5036.10 7576.78 2482.31 7158.63 7576.80 70.88 1. 95 MWD IFR MSA 105 9649.60 57.01 71.74 94.05 5086.98 7655.86 2507.12 7233.73 7655.88 70.88 0.50 MWD IFR MSA 106 9742.70 56.92 72 .69 93.10 5137.74 7733.88 2530.96 7308.05 7733.91 70.90 0.86 MWD IFR MSA - 107 9836.11 57.06 72.85 93.41 5188.63 7812.17 2554.17 7382.87 7812.20 70.92 0.21 MWD IFR MSA 108 9929.78 57.56 73.33 93.67 5239.22 7890.93 2577.09 7458.29 7890.98 70.94 0.69 MWD IFR MSA 109 10022.71 57.41 73.85 92.93 5289.17 7969.20 2599.23 7533.46 7969.26 70.96 0.50 MWD IFR MSA - 110 10117.05 57.29 72.83 94.34 5340.07 8048.55 2622.00 7609.56 8048.62 70.99 0.92 MWD IFR MSA - 111 10210.86 56.98 72 .29 93.81 5390.97 8127.31 2645.62 7684.73 8127.38 71. 00 0.59 MWD IFR MSA . - 112 10304.67 56.47 73.56 93.81 5442.44 8205.68 2668.65 7759.70 8205.77 71. 02 1.26 MWD IFR MSA - 113 10397.80 56.13 73.04 93.13 5494.12 8283.08 2690.91 7833.91 8283.19 71.04 0.59 MWD IFR MSA 114 10490.59 55.79 72.88 92.79 5546.06 8359.91 2713.44 7907.43 8360.03 71.06 0.39 MWD IFR MSA 115 10522.48 55.77 72 .40 31. 89 5563.99 8386.27 2721. 31 7932.59 8386.39 71.07 1.25 MWD IFR MSA 116 10594.00 55.77 72 .40 71.52 5604.22 8445.37 2739.19 7988.96 8445.51 71.07 0.00 Projected to TD [(c) 2003 IDEAL ID8 1C 01] - . (ill} ~ ~~~ ~~{Æ AI#ASIiA. OIL AND GAS CONSERVATION COMMISSION . FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL NO. AIO 25.02 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage Alaska 99519 Dear Mr. Crane: Area Injection Order No. 25 ("AIO No. 25"), dated February 4, 2003, authorizes underground injection of fluids for enhanced oil recovery in the Polaris Oil Pool, Prudhoe Bay Field, North Slope, Alaska. Rule 2 of AIO No. 25 authorizes underground fluid injection in specific wells enumerated in the Order. Subject Rule 2 also allows the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") administrative approval of additional Polaris injection wells. Proposed well W-215i is permitted for drilling as a service well for injection in conformance with 20 AAC 25.005. There are no other wells within a one-quarter mile radius of the proposed injection zone. AOGCC has determined that fluids injected into proposed well W-215i will enter permeable strata which can reasonably be expected to accept injected fluids at pressures less than the fracture pressure of confining strata. The Commission has further determined that injected fluids will be confined within the appropriate receiving intervals by impermeable lithology, cement isolation of the wellbore and appropriate operating conditions. Accordingly, Area Injection Order No. 25 is amended to authorize drilling and construction of Prudhoe Bay Field, Polaris Oil Pool well W - 215i. DONE in Anchorage, Alaska this 298t day of July 2003. /~ /)~.. ~ ~ tf" . tì" ~ alin Daniel T. Seamount, Jr. ~ Chair Commissioner BY ORDER OF THE COMMISSION · . ~ !Æ ~E [ill} !Æ ~!Æ ~ ~ ~ !Æ / FRANK H. MURKOWSKI, GOVERNOR AI,ASIi& OIL AND GAS / CONSERVATION COMMISSION í 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage Alaska 99519 Re: Prudhoe Bay Unit W-215i BP Exploration (Alaska), Inc. Permit No: 203-131 Surface Location: 4313' NSL, 1186' WEL, Sec. 21, T11N, RI2E, UM Bottomhole Location: 1829' NSL, 1557' EWL, Sec. 14, TIIN, RI2E, UM Dear Mr. Crane: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or 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 witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ¿:::::::: í) 17 - C:~ BY ORDER RF THE COMMISSION DATED this~ day of July, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section ~,f- '7/ z..'/l,OfJ'K . STATE OF ALASKA _ ALASKJ IL AND GAS CONSERVATION COMW$SION PERMIT TO DRILL 20 AAC 25.005 1a. Type of work III Drill 0 Redrill 1b. Type of well 0 Exploratory 0 Stratigraphic Test 0 Development Oil ORe-Entry 0 Deepen III Service 0 Development Gas 0 Single Zone 0 Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 80.80' Prudhoe Bay Field I Polaris 3. Address 6. Property Designation Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 047451 4. Location of well at surface x = 612049, Y = 5959291 7. Unit or Property Name 4313' NSL, 1186' WEL, SEC. 21, T11 N, R12E, UM Prudhoe Bay Unit At top of productive interval x = 619560, Y = 5962040 8. Well Number 1667' NSL, 1092' EWL, SEC. 14, T11N, R12E, UM W-215i At total depth x = 620023, Y = 5962209 9. Approximate spud date 1829' NSL, 1557' EWL, SEC. 14, T11N, R12E, UM 08/20/03 / Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well /14. Number of acres in property 15. Pr~sed depth (MD and TVD) ADL 028263,1557' MD W-207i is 32' away at 300' MD 2560 10610' MD I 5553' TVD 16. To be completed for deviated wells 17. Anticipated pressure {s~ 20 MC 25.035 (e) (2)} Kick Off Depth 300' MD Maximum Hole Angle 630 Maximum surface 1808 psig, At total depth (TVD) 5020' I 2310 psig 18. Casing Program S "f r Setting Depth Size pecllca Ions Top Bottom Casina Weiçht Grade Couclinç Lenath MD TVD MD TVD 20" x 34" 215.5# A53 Welded 80' 29' 29' 109' 109' 9-5/8" 40# L-80 BTC 4116' 29' 29' 4145' 2656' 7" 26# L-80 BTC-M 10581' 29' 29' 10610' 5553' 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Hole 48" 12-1/4" 8-314" Quantity of Cement (include staae data) 260 sx Arctic Set (Approx.) 724 sx PF 'L', 427 sxClass 'G' , 420 sx Class 'G' /' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD Perforation depth: measured true vertical 20. Attachments III Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch . Drilling Program III Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report . 20 AAC 25.050 Requirements Contact Engineer Name/Number: Michael TrIolo, 564-5774 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I ~erebY certify that the fO~~,~gOin, is true and ÇQrrect to the best of my ~nowl~~ge . Signed Lowell Crane ' ç-:.Æ/,~.Þ1 /~ Title Senior Drilling Engineer Date 7 ~ ;;2'fj- 0·> , ,,'," "':'::'::;<::;i:;;CQ~~Use~;;,,¡ >:C/;i{:;.." " ,,' ,," Permit Number I API Number APP[:rJ. Date/l¡?, I See cover letter .2.0, ~ - /.s I 50- 0 Z ~ - ¿ 3 J 7.2.. 0(1 fl for other requirements Conditions of Approval: Samples Required 0 Yes :ŒI No Mud Log Req Ired 0 Yes ~ No Hydrogen Sulfide Measures 0 Yes "ãI' No Directional Survey Required ø Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: T-e.s t- 'ßOPE- /-0 '-/000 ('!.-I. ML T) tLMhf-+ 'I. Ll.&J.tl1 ~ l"ûJ~r~. t'W.. . by orclér Sf I 1 / :JQ12 2 Approved By ""'I1.lnal Signed By C::;ommissioner the commission Date V)' /, / Form 10-401 Rev. 12-01-85 ~. t'8In U K 1 b I (\j A L Sub it In ~ iplic te -- Well Plan Summary I Well Name: I W-215i Greater Prudhoe Bay Polaris W-215i Permit e I Type of Well (producer or injector): 1 USH Injector Surface Location: 4,313' FSL, 1,186' FEL, Sec. 21, T11N, R12E ./ X = 61 Y = 5,959,290.84 1,667' FSL, 4,188' FEL, Sec. 14, T11 N, R12E X = 619,560 Y = 5,962,040 Z = 5,225' TVDss .r 1,829' FSL, 3,722' FEL, Sec. 14, T11N, R12E ./ X = 620,023.05 Y = 5,962,209.48 Z = 5,472' TVDss W-215i Target Start: W-215i Target End: I AFE Number: 1 PLD5M1064 I Rig: I Nabors 9ES ./ I Estimated Start Date: I Aug 20m 2003 /f I Operating days to complete: 116.13 MD 110,610' I I TVDrkb: TD I 5,553' I I Max Inc. I 63° I I KBE I 80.80' Well Design: USH Grassroots Schrader Injector. 4-%" X 3-%" TCII Completion. Current Well Information General Well Name: API Number: Well Type: Current Status: BHP: BHT: W-215i 50-029- ????? Development - Polaris Schrader Injector / New well, 20" X 34" insulat~nductor 2,310 psi @ 5,020' TVDss . ppg EMW). Normal pressure gradient. 100°F @ 5,020' TVDss Es '. ted Mechanical Condition W-209i: Nabors 9ES: Conductor: Cellar Box above MSL = 52.3' KB / MSL = 28.5' 20" X 34", 215.5Ib/ft, A53 ERW set at 109' RKB % Mile Wellbore Near Well bore Mechanical Integrity Summary: There are no penetrations within % mile of this injector penetration at the Top OA structure. ./ Target Estimates Estimated Reserves: 1,635 mstb / Expected 12 month avg: 165 bopd (from W-205 ML and W-201) Approved 7/23/03 Materials Needed Surface Casing: Intermediate Casing: L-80 Completion: - Greater Prudhoe Bay Polaris W-215i Permit e 4,145' 1 each 1 each 25 each 1 assembly 1 lot 9-%",40#, L-80 BTC Casing 9-%", BTC Float Shoe and Float Collar 9-%",40#, BTC Type TAM Port Collar 9-%" x 12 14" Bow Spring Centralizers FMC 11" 5m Gen 5 Wellhead System 9-%" casing pups 5', 10', 20'. 10,610' 1 each 65 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 14" Rigid Straight Blade Centralizers 7" casing pups 5',10',20' 7" RA Tag 7" 26# L-80 BTC-M Casing Short Joint 4 W 12.60 I bItt , L-80, TCII tubing 3 %" 9.20 I bItt, L-80, TCII tubing Baker PRM Production Packer 7" X 3-%" Baker S-3 Production Packer 7" X 3-%" Halliburton 4-%" X-Nipple (3.813" ID) Halliburton 3-%" X-Nipple (2.813" ID) 11" X 4- %" FMC tubing hanger 4-1/16", 5m Cameron Tree 4-%" x 1" KBG-2 GLM 3-%" x 1-%" MMG GLM 3-%" WLEG 9,600' 500' 2 each 1 each 2 each 4 each 1 each 1 each 1 each 4 each 1 each Surface and Anti-Collision Issues Surface Shut-in Wells: No wells need to be shut-in for the rig move on and off W-215i. / Close Approach Shut-in Wells: There are NO close approach wells requiring subsurface isolation for this profile. Close Approach Well List: I..lllill.B'il W -207i W-212 299.87-ft 695.54-ft Use Traveling Cylinder (Gyro) Use Traveling Cylinder (Gyro) 27.17-ft 48.74-ft Survey and Logging Program 12-1,4" Hole Section: Surface Gyro if needed (have discussion with ODE on photo or E-line Gyro) Open Hole: MWD I GR Cased hole: None 8-%" Hole Section: I MWD I GR I Res I Den 1 Neu I PWD (Den Neu recorded only) Cased Hole: USIT Bond Log 121,4" Surface Hole Mud Properties: Interval I Density (ppg) Funnel vis Initial 8.6 - 8.8 300 Base Perm 8.8 - 9.6 / 200 - 300 Interval TD 9.3 - 9.6 200 8 %" Intermediate Hole Mud Properties: Interval I Density (ppg) Funnel vis Initial 8.6 - 9.0 45 - 55 Ugnu I Schrader 9.5 45 - 55 Mud Program YP 50 - 70 30 - 60 25 - 48 I Spud - Freshwater Mud Tauo PH Plastic Vis FL 10-18 8.5-9.5 20-45 15-20 8 -16 8.5 - 9.5 20 - 40 < 15 9 - 14 8.5 - 9.5 14 - 20 < 10 I Freshwater Mud (LSND) PH: 8.5 - 9.5 Tauo PV API Filtrate MBT 3 - 6 9 - 14 < 5 < 20 3 - 6 11 - 15 < 5 < 20 YP 21 - 28 21 - 28 2 Approved Formation Markers (Based on IIUmberger WP4) Greater Prudhoe Bay Polaris W-215i Permit e SV5 1,830 2,483 1,911 Base Permafrost 1,850 2,528 1,931 SV4 1,975 2,806 2,056 No SV3 2,485 3,944 2,566 Poss. Gas Hydrates 2,766 Poss. Gas SV2 2,685 4,391 1,208 8.7 Hydrates SVl 3,010 5,116 3,091 1,355 8.7 Poss. Gas Hydrates UG4 3,390 5,964 3,471 1,526 8.7 No UG4A 3,430 6,053 3,511 1,544 8.7 Heavy Oil above 3800' SS UG3 3,755 6,778 3,836 1,690 8.7 Thin Heavy Oil lenses UGl 4,240 7,860 4,321 1,908 8.7 No Top Schrader Bluff/Ma 4,605 8,675 4,686 2,120 8.9 Maybe - Heavy Oil Sand Mbl 4,650 8,775 4,731 2,150 8.9 No Mb2 4,710 8,909 4,791 2,170 8.9 No 1·<;; N~· Mc 4,785 9,076 4,866 2,200 8.8 No Na 4,850 9,221 4,931 2,230 8.8 No Nb 4,880 9,288 4,961 2,250 8.9 No Nc 4,925 9,389 5,006 2,270 8.9 No OA 5,020 9,601 5,101 2,310 8.8 No OBa 5,080 9,735 5,161 2,330 8.8 Yes OBb 5,115 9,813 5,196 2,345 8.8 Yes OBc 5,165 9,924 5,246 2,360 8.8 Yes OBd 5,225 10,058 5,306 2,380 8.8 Yes OBe - Base injection 5,305 10,237 5,386 2,420 8.8 Yes interval OBf 5,355 10,348 5,436 2,435 8.7 Yes OBCBase 5,405 1 0,460 5,486 2,450 8.7 Yes TD 5,472 10,610 5,553 2,465 8.7 No CasinglTubing Program Hole Size Csgl Wt/Ft Grade Conn Length Top Bottom Tbg O.D. MD I TVDrkb MD I TVDrkb 48" 20" X 34" 215.5# A53 Welded 80' 29' /29' 109' /109' 12-%" 9-%" 40# L-80 / BTC / 4,116' 29' / 29' 4,145' /2,656' 8-3,4" 7" 26# L-80 /' BTC-M /' 10,581 ' 29' / 29' 10,610' / 5,553' Tubing 4 Y2" 12.60# L-80 TCII 9,471' 29' / 29' 9,600' / 5,101 ' Tubing 3%" 9.20# L-80 TCII 500' 9,600' / 5,101 10,100' / 5,325 Cement Calculations Casin~ Size 19-%-in 40-lb/ft L-80 BTC - Single Stage Basis I 250% excess over gauge hole in permafrost interval, 30% excess over gauge hole below permafrost Total Cement Volume: Tam Port collar located at 1,000' as a contingency for cement to surface Wash 20 bbls CW100 Spacer 75 bbls of yrsëÒsified Spacer weighted to 10.20 ppg ¡r .J-~_~.d 535 q~Is.J?î4"S~s) .1 º:_"L!~gª1 .Permafrost L cemen}.ré.~;;.4~~¡¿f!¿?k .__ . .._I9.11 .1 87:.4()._~Q_I~~42.l· s~_§»J..§.:.I~t!.I?!g~1 Class G + add~..::-:.{!_·.1Lcuft/sk . . ...._____ Temp I BHST:::: 60"'F"from SOR, BHCT 70" F estimated by Halliburton 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. 3 Approved Greater Prudhoe Bay Polaris W-215i Permit Casin~ Size 17" 261b/ft L-80 BTC-rIIl ~ Single Stage - ~ Basis I 30% excess - TOC: 600' MD above the Ma sands (planned Top Ma: 8,675' MD) => e:7~D Total Cement Volume: Wash 5 bbls CW100 --' Spacer 35 bbls Of~.i ified Spacer (Mudpush XL Design) W.~.· ted to 10.2 ppg Tail 91.3 bbls...:3 sks) 15.6Ib/gal Premium G + LXT --:-~uft!sk , Temp I BHST == 1° F from SOR, BHCT 80° F estimated by Halliburton 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 3,145' MD (1,000' MD above the shoe). b) Run 2 Bow-spring centralizers on either side of the TAM Port Collar. c) This centralizer program is subject to change pending actual hole conditions. 7" String Centralizer Placement a) Place 2 centralizers 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 8,075' 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' - 4,145' Hughes MXC-1 2x20 1x14 1x12 Interm. 8-% 4,145' -10,610' Hycalog DS70NPV 6x14 Motors and Required Doglegs BHA No. 1&2 Motor Size and Motor Required 9-%" Anadrill A962M3445SP Mud Motor, 1.5° ABH with 12- W string stabilizer 6-%" Anadrill A675M4570XP Mud motor, with 1.15° ABH with 7.0" string stabilizer Flow Rate RPMs 400 - 650 40-60 gpm 500 - 600 60-120 gpm Required Doglegs 1.5°/100' initial build . 4°/100' final build ,/ Hold 63° Tangent 3 4 Approved Well Control e Greater Prudhoe Bay Polaris W-215i Permit e 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. /" Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Section- · Maximum anticipated BHP: 2,310 psi @ 5,020' TVDss - Schrader · Maximum suñace pressure: 1,808 psi @ surface / (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned BOP test pressure: · Planned completion fluid: r;ô~ (the 7" casing will be tested to 4,000 psi) ~:~ 9.2 ppg Brine / 6.8 ppg Diesel 4,000/250 psi Rams & Valves 3,500/250 psi Annular 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. 5 Approved Greater prUdhway Polaris W-215i Permit Drillina Hazards ant Continaencies POST THIS NOTICE IN THE DOGHOUSE Well Control & A. The Schrader in this fault block is expected to be normal pressured 8.8 pg EMW. This pressure is estimated based on offset well pressures and material balance. . . Hydrates and S~ gas A. Hydrates hav no een a significant issue thus far on W -Pad during the recent drilling of W -203, W -211, W -212i, and W -207i ever there is always a potential. III. Lost Circulation/Breathing A. Lost circulation is unlikely. 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 15.6 Ib~gal . ement to 600' MD above the Ma sand -8,075' MD. C. The Kick Tolerance for the surface casing i . 2. bls with 9.2 ppg mud, 11.5 ppg LOT, and an 8.9 ppg pore pressure. If the LOT is less then 11.5 PP' W, then the kick tolerance will be < 50 bbls. D. Integrity Testing I. II. 9-%-in shoe 20-ft minimum from 9-%--in shoe LOT 11.5 minimum V. Stuck Pipe A. We do not expect stuck pipe. B. There could be slight differential sticking issues across the Ugnu. Centralizers will be run to mitigate. VI. Hydrogen S~lf e A. W Pad is 0 esignated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed H times. Waterflood on W-Pad was just initiated into the Ivishak in October 2001 and the Schrader Bluff in April 2003, and H2S levels are expected to remain low until the waterflood matures. Recent H2S data from the pad is as follows: B. Adjacent producers at Surface: a. W-1 0 ppm b. W -207i 0 ppm C. Adjacent producers at TD: a. W -203 0 ppm ~W~O~ / D. The maximum level of H2S recently recorded on the pad was under -10 ppm. VII. Faults A. One fault is planned to be crossed up in the UGNU after the surface casing shoe. This fault has been crossed on numerous wells and is not expected to cause any drilling problems. The fault details are listed below for reference: Fault #1: 6,300' MD 3,622' TVD 3,541' TVDss Throw: 40' West CONSULT THE W PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 6 Approved Greater Prudho~e Bay Polaris W-215i Permit Drill an!If.Jii~;J~:Ja.l'Í=l'fITT:Ì;.·ÍJmmary Pre-Rig Work: 1. A conductor has already been set for W -215i. / 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. ***AII pre-rig work should be charged off against the predrill AFE # PLD5M1064*** Rig Operations: 1. MIRU Nabors 9ES. / 2. Nipple up diverter spool and function test diverte/ 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 4,145' MD. The actual surface hole TD will be +/-90' TVD bel~he top of the SV3 sands. 4. Run and cement the 9-%", 40.0-lb/ft. surface casing back to surface. A TAM Port collar or stage tool will be run in the casing string to allow secondary cementing, in the event cement is not circulated to surface during primary cementing operations. . 5. ND diverter spool and NU casing / tubing head. NU BOPE and test to 4,000 psi. /" 6. MU 8-3,4" drilling assembly "",ith MWD/GR/Res/Den/Neu(recorded)/PWD and RIH to float collar. Test the 9-%" casing to 3,500 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 (minimum 11.5 ppg EMW). 9. Drill ahead to TD at 10,610' MD, the base of Schrader formation. ,/ 10. Perform wiper trip and condition the hole for casing. POOH standing back the 4" DP. /' 11. Run and cement the 7" production casing as required to cover all significant hydrocarbon intervals. Displace the casing with 9.2 ppg mud or seawater during cementing operations and freeze protect the 7" x 9-%" annulus. 12. PU used bit/scraper/GR and RIH with 4" DP while waiting on cement. Position GR sensor in MWD tool at ±9,785' or as near to it as possible. Log up one full stand to find the top of the OBa sand and RA tag if possible. Continue in the hole to PBTD ±10,530' MD. Displace out the mud / seawater with 9.2 ppg brine. Spot 20,000 LSRV perf pill from PBTD to 200' MD above OBa. POOH and LD BHA. 13. RU Schlumberger E-line and run a USIT log. ,,/ 14. RU Halliburton and PU 140' of 4-%" Millenium 5 spf perforation assembly with -294' of spacer pups. RIH to perforation depth based on previous logging run, space out and perforate. 15. PU to above top perf and circulate wellbore, monitor for losses. POOH, LD perforation assembly. 16. MU cleanout assembly with bit and 7" casing scraper, run to bottom and circulate and cleanup any perf debris and perf pill. Design assembly for rotation. POOH and LD 4" DP and cleanout assembly. ../' 17. Run the 4-%" X 3-%", L-80 TCII completion with a 7" x 3-'112" straddle packer assembly and GLM's for injection. 18. Run in the lockdown screws and set the packers. Test the production casing/tubing annulus and tubing to 4,000 psi each:'" Run in a positive plug in the XN-nipple with Slickline. Shear the DCK shear valve. 19. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. 20. Freeze protect the well to -2,200' TVD. // 21. Rig down and move off. 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. Tag TD with slickline 4. Pull dummy valves in injection mandrels and replace with injection valves 7 Approved Greater Prudhoe Bay Polaris W-215i Permit ,,'" ------ Job 1: MIRU Hazards and Contingencies: ~ 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). ~ Ensure the AOGCC receives 24-hour advance notification of the diverter test and subsequent BOP tests. ~ No wells are required to be shut in. Job 2: Dril/12W' Surface Hole Hazards and Contingencies: ~ At W-Pad, no significant surface hole drilling problems have been identified. Minor tight hole has been encountered in the clay sections below the permafrost, some lost circulation thought to be in conjunction with the tight hole, possible packing off has been encountered. ~ Close Approach: No wells are required to be shut in. There are several close tolerance wells in the surface interval. Follow the traveling cylinder / no-go plot per established procedures. Should not need to run a gyro. Magnetic interference is expected to be minimal. ~ Directional: Every effort should be made to ensure a 'smooth' well profile that will benefit torque / drag in the later hole sections. A graduated build profile is planned. Obiective is to keep DLS ~1 0 over planned. ~ ~ 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 1.50 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 tlowrates should be increased to 650 - 700 GPM to increase hole cleaning. ~ Drill Pipe specs: from Premium classification, not New. 5",19.5#,4-%" IF, 'G' ID Collapse 100% 4.276 8,765 psi 80% 3.250(tool joint) 7,012 psi ***Max Recommended MU Torque: 26,800 ft-Ibs ***Min Recommended MU Torque: 25,900 ft-Ibs ~ 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. Burst 12,526 psi 10,021 psi Torsional 45,200 Ibs 36,200 Ibs Tensile 436,100lbs 348,880 Ibs ~ 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. Job3: Install Surface CasinQ Hazards and Contingencies: ~ Casing to bottom: It is imperative the casing is set in the shale below the SV3 sands to ensure wellbore integrity for the intermediate interval. 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 insure circulation is attained at TD at the desired cementing rates without losses. ~ Casing drift: 9-%" special drift casing is being used (8.835" drift required). Ensure that casing equipment is properly drifted to ensure adequate ID for the 8-%" bit, Le. float equipment, casing hanger, etc. 8 Approved _ Greater Prudho.e Bay Polaris W-215i Permit ~ Cement to surface: A singl~.:stage job will be done on this well using 2.0 excess in the permafrost and 30% excess below the permafrost. As we will be downsizing the nozzles on the bit this may increase hole erosion slightly due to the extra nozzle velocity. A TAM Port collar will be placed at 1 ,OOO-ft MD. ~ Losses during cement job: At W-Pad lost circulation has been experienced while running and cementing surface casing on past wells. The expected frac gradient for the shale below the SV3 sands is 12.5-lb/gal EMW. Follow the Halliburton 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. Job 4: Drill 8%" Production Hole Hazards and Contingencies: ~ Differential Sticking could be a problem if lost circulation is occurring or if the drill string is left stationary for an extended period or time across the permeable Schrader Sands. ~ LOT: Perform a LOT (minimum 11.5 ppg EMW to satisfy kick tolerance). KICK TOLERANCE: Based upon the max expected Schrader reservoir pressure of 8.9 ppg and a 9.2 ppg mud, an 11.5 ppg leak-off will provide just over 50 bbls of kick tolerance. Contact Anchorage personnel if LOT is less than 11.5 ppg. Based upon off- set drilling data on W-Pad, a minimum leak-off of 12.5 ppg is expected at the 9-%" shoe. ~ 7" casing landing point: The landing point for the 7" casing 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' MD past this base. This footage is critical for future wellwork. 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. ~ Torque: Modeling indicates that high torque values, in the 12,000 to 13,500-ftlb range can be expected by section TD. Use lubricants as per the MI program. If weight transfer problems are encountered during sliding, attempt to circulate and rotate for a minimum of 2 BU 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 point for this hole section. As mentioned above in the landing point discussion, the landing of this well will depend on picking the base OBf sand which will be picked by Gamma Ray. Therefore if we loose the GR tool, we will need to trip for it. ~ Faults: One fault is planned to be crossed up in the UGNU after the surface casing shoe. This fault has been crossed on numerous wells and is not expected to cause any drilling problems. The fault details are listed below for reference: Fault #1: 6,300' MD 3,622' TVD 3,541' TVDss Throw: 40' West ~ Directional Constraints: It is critical to not let the angle get any higher then planned, due to slickline access requirements. It is critical to design a BHA to minimize inclination walking tendencies to minimize wellbore tortuousity. DLS should be kept ~1 0 over planned. Job 6: Install 7" Production CasinQ Hazards and Contingencies: ~ Tight hole, packing off and lost circulation have been experienced while running casing though this interval. Good hole cleaning and mud conditioning are required for running this string. ~ Centralization/Differential Sticking: See centralizer strategy under Section 3: Drilling Program Overview. 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: Pip # 1: TBD, Pip #2: TBD ~ Cement Job: It is imperative to achieve a good cement job on this well due to the water wet OA sands. Good zonal isolation of this sand is imperative to the production success of this well. 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. 9 Approved Greater Prudhoe Bay Polaris W-215i Permit Keep cementing ECD's beloA5 ppg EMW during the displacement. e ~ Mud Requirements: Thin the mud as per MI's Mud Program. The thinner the mud the better displacement is achieved and the better the cement job will be. Extra time spent circulating is warranted to ensure optimum mud properties and hole cleaning prior to the cement job. ~ Franks Casing Fill-up tool: Make sure that a casing fill up tool is on location prior to PU 7" casing. ~ 7" Casing Specifications: 7", 26#, L-80 BTC 100% 80% ID 6.276 6.151 (drift) Collapse 5,410psi 4,328psi Burst 7,240psi 5,792psi Tensile 667,OOOlbs 533,600lbs ~ TIW Valve: Ensure that a TIW valve with a cross over to 7" BTC casing is on the rig floor !:imm;!.~.~....__.......~_~:__________:_~-'_,·'_·_""-"'! T:_-='!. ;;,'" <J.ii-:51__.~_~~ Job 10: DPC Perforate Well Hazards and Contingencies ~ The well will be perforated ±105 psi over-balanced. Ensure all personnel are well briefed on Halliburton'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, perforating crew and the Halliburton hand. 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 Halliburton to prepare for approximately 140' of 4-%" Millennium charge guns at 6 spf. Exact perforation depths will be provided after reviewing the LWD logs. ~ Be prepared for fluid losses to the formation after perforating. Have ample seawater on location and be prepared with LCM if necessary. Follow the LCM decision tree for "After Perforating". Position guns either by DP measurement based on previous logging I cleanout trip or by utilizing the Schlumberger GR tool in the string. Reference RP: .:. 'Halliburton DPC Procedure' o,-,,;~),:,"<,_ Job 12: Run Completion Hazards and Contingencies: ~ Dirty Hole: It is critical to have a clean hole to run this completion in due to the production packer. Take time if deemed necessary to run a GR/JB. If the packer partially prematurely sets, set it all the way and run in and chemical cut and remove the completion. Reference RP: .:. 'Completion Design and Running' RP '<»='»,""~~~",J ,.. __~_~< ~~_:w> -"~- Job 13: ND/NU/Release RiQ Hazards and Contingencies: ~ Diesel will be used to freeze protect the well. The diesel flash point Is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. 10 Approved TAM Port 9-5/8",40 #/ft., BTC -THD' TVDss -THD'TVDss '" 7/23/03 Mik packoff 20" 1 'X' TVDj with seal bore, Cameo gas lift mandrel 4~1/2" xi" KBG2 With DCR Shear Valve pinned to 2,500 ;" 4~1/2", 12.75 Ib/ft, L-80, TCII Drift 1 ID: 3.833"/3.958" 3-1/2", 9.3 Ib/ft, L-80, TCII Drift 1 ID: 2.867"/2.992" Packer OBa perf 2.813" seal bore. Production with bore. Cameo 3-1/2" x 1~1/2" Injection Mandre! III! Production Packer with seal bore. above OBd - .... ...... .... .... .... .... ..... ~Bd ..... 7", PBTD MD 7",26 BTC-Mod III '" 11II ^ ^ ^ z g o o o ... II () ri C/) C/) V V V -1000 WEll MagnelicParametefs Model: PGGM 2002 o 3000 "....·..'1"'....··....."..·...., 2000 Plan W-215 Dip: 80.782' MagOec: +25.538' Date AugtlSt25,2003 FS: 57526.7nT 1000 2000 ",:J{~~, ¡ _J,_..j,..........,.. ~~.........>........."'...." , . ':8'<' ' "'~~" ;':""-'- . . ',.,'. j_,r < ,'".".....~,....,.. ."........"........, ...........,.,.......... · . , , , ............ ...........,. .........'.'.. .........~.........................,..,.......,. , . , · . . · . . · . . · . . · . . · . . , , . · . . , . ' ...,........................,........, K01 Bid 1/100 1000 o ,.........<............. o ..........~..., ,.......,.........." u...........,......,.< 1000 2000 Schlumberger FIELD Prudhoe Bay Unit - WOA ,TRUCWR' W-PAD SurfaœlocatiOfl La! N701751.817 Lorr W149533.367 NAD27 AI¡¡ska Slate Planes, Zooe 04. US Feet Northing: 5959290,84 nus Grid Cony: +0.85428445" Easling 612048.97I1.US $calaFacI: 0.9999142622 Miscellaneous Slot W-215 Plan" W·215 (P4) 3000 4000 5000 · , ..""..........""....."..""....,...,,,......... · ' · . · . · , · . · . · . · . · . · , · , · . · . · . · . , . · . · . · . · . , . · . , . , . , . , , , , · , · , · , · . , . · . , . · . · , · , ·n'....... .,',.....~......",......, ",......................, · . · . · . · . · . · . ¡ -W·215FI11 TVORd: KB(80.80ftaboveMSl) StvyOale: July07,2003 6000 8000 7000 ".....~."..".................... . ................,...........,..~.....,...........,..."......., ."".....".....,.................. · , .......',.....,.....................................................~........,.....," .............................,. · , · , , , , , , . , , ,....."1'............... ...........,..,............"1"....,.,.. ..~..., ,...............,...............~.... · , · , · , · . · . · . · , · . · , , , ,,'..........,............ ..................."".... ,...........,'......... ,.........~.............. ............... ......................... ,".........·..·,................00... 3000 4000 5000 «< W Scale = 1: 1 OOO(ft) E »> , . ..,,'..........,...................................,.,.............,..............,. · . , . , . , . · . · , · . · . · . · . · . · . · . · . , . · . . "..H.~......,.........................".'?.....,',............,.........."...t.......".. · . . , . . , . 6000 8000 7000 . 3000 2000 1000 , o -1000 1000 Schlumberger WELL FIELD Prudhoe Bay Unit - WOA STRUCTURE W-PAD Plan W-215 MagnelicParameten; Modal: BGGM2002 SUlfaceLocation Lat N701751.B17 Lon W149533.367 NAD27 Alaska State Planes, Zone 04, US Feet Northing: 5959290.84 ftUS GOd Conv: +0.85428445' Easting: 612048.97 flUS Scale Fact: 0.9999142622 Miscellaneous Slol- W·215 Plan: W-215 (P4) Dip; 80.782" MagDac:: +25.538' Date- August25,2003 FS' 57526.7nT TVD Ref: KB (80.80 ft above MSl) SrvyDate: JuIy07,2003 o 1000 2000 3000 4000 5000 6000 7000 8000 9000 o o KOP Bid 1/100 -- Bid 2,5/100 - _Bid 41100 . 1000 2000 2000 a? Õ 0 0 ..... II () ro 3000 3000 <.> rJ) 0 ¡:: . 4000 4000 5000 " 5000 ,I.lral: ." "I . ," ,,' (, 0" _,11; :..~,: ....,.:,.:¡."~....:¡ o 1000 2000 3000 4000 5000 6000 Vertical Section (ft) Azim = 70.75°, Scale = 1:1000 Origin = 0 N/-S, 0 E/-W 7000 8000 9000 KBE KOP Bid 1/100 Bid 2,5/100 Bid 4/100 End Bid SV5 Schlumbørgør Report Date: Client: Field: Structure I Slot: Well: Borehole: UWI/API#: Survey Name I Date: Tort I AHD I DDII ERD ratio: Grid Coordinate System: Location Lat/Long: Location Grid N/E Y IX: Grid Convergence Angle: Grid Scale Factor: W-215 (P4) Proposal July 7, 2003 Survey I DLS Computation Method: BP Exploration Alaska Vertical Section Azimuth: Prudhoe Bay Unit - WOAdY Vertical Section Origin: W-PAD/W-215 III I lilt)' stu TVDReferenceDatum: Plan W-215 III b I I TVD Reference Elevation: W-215 Feasl Sea Bed I Ground Level Elevation: 50029 Magnetic Declination: W-215 (P4) 1 July 7,2003 Total Field Strength: 63.374° 18492.18 ft/6,012/1.529 Magnetic Dip: NAD27 Alaska State Planes. Zone 04, US Feet Oeclination Oate: N 70.29772700, W 149.09260204 Magnetic Declination Model: N 5959290.840 ftUS, E 612048,970 ftUS North Reference: ..0.85428445° Total Corr Mag North .) True North: 0.99991426 Local Coordinates Referenced To: Minimum Curvature I Lubinski 70,750° N 0.000 ft, E 0.000 ft KB 80.8 ft relative to MSL 47.830 ft relative to MSL 25.538° 57526.717 n T 80,782° August 25, 2003 BGGM 2002 True North +25.538° Well Head Comments Measured Oepth (ft) 0.00 300.00 400.00 500.00 600.00 Inclination (deg) 0.00 0.00 1.00 3.50 7.50 11.50 15.50 19.50 23.50 27.50 31.50 35.50 39.50 43.50 47.50 51.50 55.50 59.50 63.37 63.37 Azimuth (deg) 70.75 70.75 70.75 70.75 70.75 70.75 70.75 70.75 70,75 70.75 70.75 70.75 70.75 70.75 70.75 70.75 70.75 70.75 70.75 70.75 TVO (ft) 0.00 300.00 399.99 499.91 599.43 698.04 795.26 890.61 983.63 1073.87 1160.89 1244.26 1323,58 1398.46 1468.54 1533.47 1592.94 1646.66 1692.95 1910.80 Version DO 3.1 RT ( d031 rL399 ) 3.1 RT Service Pack 2.03 700.00 800.00 900.00 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 1800.00 1900.00 1996.85 2482.93 Sub·Sea TVO (ft) -80.80 219.20 319.19 419.11 518.63 617.24 714.46 809,81 902.83 993.07 1080.09 1163.46 1242.78 1317.66 1387.74 1452.67 1512.14 1565.86 1612.15 1830.00 Vertical Section (ft) 0.00 0.00 0.87 4.80 14.38 30.88 54.22 84.29 120.93 163.97 213.20 268.39 329.25 395.50 466.81 542.83 623.20 707.53 792.57 1227.10 NS (ft) 0.00 0.00 0.29 1.58 4.74 10.18 17.88 27,79 39.87 54.06 70.29 88.48 108.55 130.39 153.90 178.96 205.46 233.25 261.29 404.55 EW (ft) 0.00 0.00 0.82 4.53 13.58 29,16 51.19 79.57 114.17 154.80 201.28 253.38 310.84 373.39 440.71 512.49 588.36 667.97 748.26 1158.50 DLS (deg/100 ft) 0.00 0.00 1.00 2.50 4.00 /' 4.00 4,00 4.00 4,00 4.00 W-215\Plan W-215\W-215\W-215 (P4) Tool Face (deg) 70.75M 70.75M 70.75M 70.75M O.OOG O.OOG O.OOG O.OOG O.OOG O.OOG 4,00 4.00 4.00 4.00 4.00 O.OOG O.OOG O.OOG O.OOG O.OOG 4.00 4.00 4.00 4.00 0.00 O.OOG O.OOG O.OOG O.OOG O.OOG Northing (ftUS) 5959290.84 5959290.84 5959291.14 5959292.49 5959295.78 5959301.45 5959309.48 5959319.81 5959332.40 5959347.19 5959364.11 5959383.08 5959404.00 5959426.77 5959451.28 5959477.40 5959505.03 5959534.01 5959563.23 5959712.58 Easting (ftUS) 612048.97 612048,97 612049.79 612053.48 612062.47 612077.97 612099.88 612128.11 612162.52 612202.94 612249.17 612300.98 612358.13 612420.34 612487.30 612558.69 612634.15 612713.33 612793.19 613201.21 . Latitude Longitude N 70.29772700 W 149.09260204 N 70.29772700 W 149.09260204 N 70.29772779 W 149.09259537 N 70.29773132 W 149.09256536 N 70.29773995 W 149.09249211 N 70.29775482 W 149.09236596 N 70.29777584 W 149.09218754 N 70.29780291 W 149.09195771 N 70.29783591 W 149.091. N 70.29787468 W 149.091 N 70.29791902 W 149.09097220 N 70.29796871 W 149.09055035 N 70.29802352 W 149.09008506 N 70.29808318 W 149.08957861 N 70.29814740 W 149.08903346 N 70.29821586 W 149.08845226 N 70.29828823 W 149.08783785 N 70.29836415 W 149.08719322 N 70.29844073 W 149.08654307 N 70.29883195 W 149.08322099 Generated 7/7/2003 11 :29 AM Page 1 of 2 Comments Measured Inclination Azimuth TVD Sub-Sea TVD Vertical I NS EW I DLS I Tool Face Northing Easting Latitude Longitude Depth Section (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) ~ deg/100 ft) (deg) (ftUS) (flUS) Base Perm 2527.56 63.37 70.75 1930.80 1850.00 1267.00 417.70 1196.17 0.00 O.OOG 5959726.29 613238.67 N 70.29886786 W 149.08291599 SV4 2806.47 63,37 70.75 2055.80 1975.00 1516.33 499,90 1431.56 0.00 O.OOG 5959811.98 613472.79 N 70.29909232 W 149.08100973 SV3 3944.44 63.37 70.75 2565.80 2485.00 2533.62 835.28 2391.98 0,00 O.OOG 5960161.61 614428.02 N 70.30000787 W 149.07323174 9-518" Csg pt 4145.26 63.37 70.75 2655.80 2575.00 2713.14 894.46 2561.46 0.00 O.OOG 5960223.31 614596.59 N 70.30016940 W 149.07185908 SV2 4390.70 63.37 70.75 2765.80 2685.00 2932.56 966.80 2768.61 0.00 O.OOG 5960298.72 614802.61 N 70.30036682 W 149.07018136 SV1 5115.88 63.37 70.75 3090.80 3010.00 3580.83 1180.52 3380.64 0.00 O.OOG 5960521.52 615411.34 N 70.30095000 W 149.06522426 UG4 5963.78 63.37 70.75 3470.80 3390.00 4338.81 1430.40 4096.24 0.00 O.OOG 5960782.03 616123.07 N 70.30163170 W 149.05942791 UG4A 6053.03 63.37 70.75 3510.80 3430.00 4418.59 1456.71 4171.57 0.00 O.OOG 5960809.45 616197.99 N 70.30170345 W 149.05881775 UG3 6778.21 63.37 70.75 3835.80 3755.00 5066.87 1670.43 4783.60 0.00 O.OOG 5961032.25 616806.71 N 70.30228632 W 149.05386001 UG1 7860.39 63.37 70.75 4320.80 4240.00 6034.29 1989.36 5696.93 0.00 O.OOG 5961364.74 617715.11 N 70.30315588 W 149.0464!t Ma 8674.82 63.37 70.75 4685.80 4605.00 6762.34 2229.39 6384.29 0.00 O.OOG 5961614.96 618398.75 N 70.30381010 W 149.04089 Mb1 8775.23 63.37 70.75 4730.80 4650.00 6852.10 2258.98 6469.03 0.00 O.OOG 5961645.81 618483.04 N 70.30389074 W 149.04020571 Mb2 8909.11 63.37 70.75 4790.80 4710.00 6971.79 2298.44 6582.02 0.00 O.OOG 5961686.94 618595.41 N 70.30399827 W 149.03929026 Me 9076.46 63.37 70.75 4865.80 4785.00 7121.39 2347.76 6723.26 0.00 O.OOG 5961738.36 618735.89 N 70.30413266 W 149.03814594 Na 9221.49 63.37 70.75 4930.80 4850.00 7251.04 2390.50 6845.66 0.00 O.OOG 5961782.92 618857.63 N 70.30424913 W 149.03715418 Nb 9288.43 63.37 70.75 4960.80 4880.00 7310.88 2410.23 6902.16 0.00 O.OOG 5961803.49 618913.82 N 70.30430289 W 149.03669644 Ne 9388.84 63.37 70.75 5005.80 4925.00 7400.64 2439.82 6986.90 0.00 O.OOG 5961834.34 618998.11 N 70.30438352 W 149.03600983 OA 9600.82 63.37 70.75 5100.80 5020.00 7590.14 2502.29 7165.80 0.00 O.OOG 5961899.46 619176.04 N 70.30455372 W 149.03456029 OBa 9734.69 63.37 70.75 5160.80 5080.00 7709.82 2541.75 7278.79 0.00 O.OOG 5961940.60 619288.42 N 70.30466122 W 149.03364479 OBb 9812.79 63.37 70.75 5195.80 5115.00 7779.63 2564.76 7344.70 0.00 O.OOG 5961964.59 619353.98 N 70.30472392 W 149.03311074 OBe 9924.36 63.37 70.75 5245.80 5165.00 7879.37 2597.64 7438,86 0.00 O.OOG 5961998.87 619447.62 N 70.30481349 W 149.03234780 T arget 1 0058.23 63.37 70.75 5305.80 5225.00 7999.05 2637.10 7551.85 0.00 O.OOG 5962040.00 619560.00 N 70,30492097 W 149.03143227 OBd 10058.26 63.37 70.75 5305.81 5225.01 7999.07 2637. 11 7551.87 0.00 O.OOG 5962040.01 619560.02 N 70.30492099 W 149.03143211 OBe 10236.74 63.37 70.75 5385.80 5305.00 8158.62 2689.71 7702,50 0.00 O.OOG 5962094.84 619709.84 N 70.30506428 W 149.03021155 OBr 10348.30 63.37 70.75 5435.80 5355.00 8258.35 2722.59 7796.66 0.00 O.OOG 5962129.12 619803.49 N 70.30515384 W 149.02944859 10459.87 63.37 70.75 5485.80 5405.00 8358.09 2755.47 7890.82 0.00 O.OOG 5962163.40 619897.14 N 70.30524339 W 149.0'86' OBr Base 10459.89 63.37 70.75 5485.81 5405.01 8358.11 2755.47 7890,84 0.00 O.OOG 5962163.41 619897.16 N 70.30524341 W 149.0286 TO I 7" Csg 10609.87 63.37 70.75 5553.02 5472.22 8492.18 2799.68 8017.42 0.00 O.OOG 5962209.48 620023.05 N 70.30536380 W 149,0276 LeQal Description: NorthinQ (Y) IftUSl EastínQ IX} IftUSl Surface : 4313 FSL 1186 FEL S21 T11N R12E UM 5959290.84 612048.97 Target: 1667 FSL 4188 FEL S14 T11N R12E UM 5962040.00 619560.00 BHL: 1829 FSL 3722 FEL S14 T11N R12E UM 5962209.48 620023.05 Version DO 3.1 RT ( do31 rL399 ) 3.1 RT Service Pack 2.03 W-215\Plan W-215\W-215\W-215 (P4) Generated 7/7/2003 11 :29 AM Page 2 of 2 " BPX AK Anticollision Report - Company: ,Field: Reference Site: Reference Well: Reference Wellpath: BP Amoco Prudhoe Bay PB W Pad Plan W-215 Plan W-215 Date: 717/2003 Time: 11 :28:40 Page: Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: Plan W-215. True North W-215 Plan 80.8 NO GLOBAL SCAN: Using user defined selection & sean criteria Interpolation Method: MD + Stations Interval: 50.00 ft Depth Range: 28.50 to 10609.87 ft Maximum Radius: 3000.00 ft Reference: Error Model: Sean Method: Error Surface: Db: Sybase --.. --.--...--. Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 2/27/2002 Validated: No Planned From To Survey ft ft 28.50 1100.00 Planned: Plan #4 V2 1100.00 10609.87 Planned: Plan #4 V2 Version: 4 TooJcode Tool Name GYD-GC-SS MWD+IFR+MS Gyrodata gyro single shots MWD + IFR + Multi Station Casing Points __._....._ .... ___._.~_'._. 0....._____."_,_ MD TVD Diameter Hole Size Name ft ft in in ---. .... ..-.....- .. 4145.26 2655.80 9.625 12,250 95/8" 10609.87 5553.02 7.000 8.750 7" Summary <--- Offset Wellpath > Reference Offset Ctr-Ctr No-Go Allowable Site Well Well path MD MD Distance Area Deviation Warn~ ft ft ft ft ft .-.,.---...-. PB W Pad Plan W-202 Plan W-202 V3 Plan: W- 455.94 450.00 586.97 9.62 577.36 Pass: Major Risk PB W Pad Plan W-204 Plan W-204 V3 Plan: W- 1045.84 1000.00 539.66 21.12 518.57 Pass: Major Risk PB W Pad Plan W-205 Plan W-205 OBd V6 plan 442.36 450.00 611.58 8.33 603.26 Pass: Major Risk PB W Pad Plan W-206 Plan W-206 V3 Plan: W- 484.82 500.00 682,29 10.00 672.29 Pass: Major Risk PB W Pad Plan W-208 Plan W-208 V2 Plan: W- 401.62 400.00 656,21 8.70 647.50 Pass: Major Risk PB W Pad Plan W-209 Plan W-209 V4 Plan: PI 448.26 450.00 161.66 7.88 153.78 Pass: Major Risk PB W Pad Plan W-210 Plan W-210 V3 Plan: W- 966.26 950.00 990.59 19.19 971.40 Pass: Major Risk PB W Pad Plan W-213 Plan W-213 V3 Plan: W- 902.62 900.00 88.76 18.26 70.50 Pass: Major Risk PB W Pad Plan W-214 Plan W-214i V4 Plan: W 647.50 650.00 20,93 12,96 7.97 Pass: Major Risk PB W Pad Plan W-216 Plan W-216 V11 Plan: W 958.49 1000.00 602.26 17.89 584.48 Pass: Major Risk PB W Pad Plan W-217 Plan W-217 V3 Plan: W- 456.49 450.00 622.01 9.74 612.27 Pass: Major Risk PB W Pad Plan W-218 Plan W-218 V3 Out of range PB W Pad Plan W-219 Plan W-219 V4 Out of range PB W Pad Plan W-220 Plan W-220 V1 Out of range PB W Pad Plan W-221 Plan W-221 V4 Out of range PB W Pad W-01 W-01 V1 396.43 400,00 192.26 7.48 184.78 Pass: Major Risk PB W Pad W-02 W-02 V4 445.14 450.00 226.56 7.08 219.49 Pass: Major Risk PB W Pad W-02 W-02A V20 446.29 450,00 226.57 7.10 219.48 Pass: Major Risk PB W Pad W-03 W-03 V4 485.32 500.00 262.34 8.62 253.72 Pass: Major Risk PB W Pad W-03 W-03A V1 492.80 500.00 262.49 8.79 253,71 Pass: Major Risk PB W Pad W-04 W-04 V1 436.11 450.00 296,83 7.58 289.25 Pass: Major Risk PB W Pad W-05 W-05 V1 436.08 450.00 331.94 8.01 323.92 Pass: Major Risk PB W Pad W-06A W-06A V2 443.05 450.00 402.00 8.53 393.48 Pass: Major Risk PB W Pad W-06 W-06 V1 443.05 450.00 402.00 8.53 393.48 Pass: Major Risk PB W Pad W-07 W-07 V1 483.22 500.00 369.23 10.74 358.49 Pass: Major Risk PB W Pad W-08 W-08 V1 481.80 500.00 437.35 8.37 428.98 Pass: Major Risk PB W Pad W-08 W-08A V11 487.34 500.00 437.45 8.20 429,25 Pass: Major Risk PB W Pad W-09 W-09 V1 339.04 350.00 471.81 7.09 464.72 Pass: Major Risk PB W Pad W-10 W-10 V3 442.47 450.00 507.48 8.65 498.83 Pass: Major Risk PB W Pad W-10 W-10A V4 442.47 450.00 507.48 8.65 498.83 Pass: Major Risk PB W Pad W-11 W-11 V1 479.66 500.00 542.77 8,50 534.27 Pass: Major Risk PB W Pad W-12A W-12A V3 440.92 450.00 578.75 9.06 569.69 Pass: Major Risk PB W Pad W-12 W-12 V1 440.92 450,00 578.75 9.06 569.69 Pass: Major Risk PB W Pad W-15 W-15 V1 792.84 800.00 122.89 13.03 109.86 Pass: Major Risk PB W Pad W-15 W-15A V10 792,84 800.00 122.89 13,03 109.86 Pass: Major Risk PB W Pad W-15 W-15PB1 V6 792,84 800.00 122.89 13,03 109.!¡6 Pass: Major Risk PB W Pad W-15 W-15PB2 V1 792.84 800.00 122.89 13,03 109.86 Pass: Major Risk PB W Pad W-16 W-16 V3 843.98 850.00 154.98 14,05 140.92 Pass: Major Risk PB W Pad W-17 W-17 V1 902.84 900.00 185,51 15.80 169.72 Pass: Major Risk PB W Pad W-18 W-18 V1 953.11 950.00 218.41 17.12 201.30 Pass: Major Risk PB W Pad W-19 Plan#11 W-19AL 1 V1 Pia 956,20 950.00 250.64 16.00 234.64 Pass: Major Risk PB W Pad W-19 W-19 V2 949.65 950.00 250.53 15.74 234.79 Pass: Major Risk PB W Pad W-19 W-19A V1 956.20 950.00 250.64 15.83 234.81 Pass: Major Risk . BPX AK . Anticollision Report .-...-....-----....'.-.-"......-."-.." ",.--..- Company: BP Amoco Date: 7/7/2003 Time: 11 :28:40 Page: 2 Field: Prudhoe Bay Reference Site: PB W Pad Co-ordinate(NE) Reference: Well: Plan W-215. True North Reference Well: Plan W-215 Vertical (TVD) Reference: W-215 Plan 80.8 Reference Wellpath: Plan W-215 Db: Sybase _._.._----~._.._. Summary < Offset Wcllpath ~ Referencc Offset Ctr-Ctr No-Go Allowable Site Wcll Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft ,/ -------~ PB W Pad W-200PB1 W-200PB1 V7 1173.47 1150.00 447.13 20.51 426.63 Pass: Major Risk PB W Pad W-200 W-200 V4 Plan: Undefin 1173.54 1150.00 447.04 20.43 426.62 Pass: Major Risk PB W Pad W-201 W-201 V4 1189.68 1150,00 477.25 19.88 457.37 Pass: Major Risk PB W Pad W-203 W-203 V9 390.13 400,00 646.48 6.35 640.13 Pass: Major Risk PB W Pad W-203 W-203L 1 V7 390.13 400,00 646.48 6.14 640.34 Pass: Major Risk PB W Pad W-203 W-203L2 V3 390.13 400.00 646.48 6.14 640.34 Pass: Major Risk PB W Pad W-207 W-207 V10 299,87 300.00 32.43 5.27 27.17 Pass: Major Risk PB W Pad W-207 W-207PB1 V2 299.87 300.00 32.43 5.27 27.17 Pass: Major Risk PB W Pad W-20 W-20 V1 1008.04 1000.00 285.25 16,76 268.50 Pass: Major Risk PB W Pad W-211 W-211 V8 572.28 600.00 265.93 9.54 256.64 Pass: Major Risk PB W Pad W-212 W-212 V12 695.54 700.00 58,98 10.49 48.74 Pass: Major Risk PB W Pad W-21 W-21 V3 1106.53 1100,00 314.97 25.71 289.27 Pass: Major Risk PB W Pad W-21 W-21A V12 1114.95 1100.00 314.95 25.75 289.21 Pass: Major Risk PB W Pad W-22 W-22 V1 1060.92 1050.00 347.54 19,44 328.10 Pass: Major Risk PB W Pad W-23 W-23 V3 1060.12 1050.00 384.31 17.69 366.63 Pass: Major Risk PB W Pad W-23 W-23A V5 1067.50 1050.00 384,39 17.84 366.55 Pass: Major Risk PB W Pad W-24 W-24 V1 1120.40 1100,00 418.42 21.59 396.83 Pass: Major Risk PB W Pad W-25 W-25 V1 338.13 350.00 260.83 7.19 253.65 Pass: Major Risk PB W Pad W-26A W-26A V3 374.68 350.00 261.47 7.38 254.10 Pass: Major Risk PB W Pad W-26 W-26 V1 346.99 350.00 261.19 7.01 254.18 Pass: Major Risk PB W Pad W-27 W-27 V1 386.47 400,00 265.77 6.89 258.88 Pass: Major Risk PB W Pad W-29 W-29 V1 432.40 450.00 287.60 8.95 278.65 Pass: Major Risk PB W Pad W-30 W-30 V1 434,13 450.00 303,98 7.80 296.18 Pass: Major Risk PB W Pad W-31 W-31 V1 480,37 500.00 323.43 9.30 314.14 Pass: Major Risk PB W Pad W-32 W-32 V5 434.47 450.00 346.29 9.39 336.91 Pass: Major Risk PB W Pad W-32 W-32A PB1 V12 437.07 450.00 346.34 9.14 337.19 Pass: Major Risk PB W Pad W-32 W-32A V3 437.07 450.00 346.34 9.40 336.94 Pass: Major Risk PB W Pad W-34 W-34 V1 384,88 400.00 364.00 6.56 357.44 Pass: Major Risk PB W Pad W-34 W-34A V1 384,88 400.00 364.00 6.56 357.44 Pass: Major Risk PB W Pad W-35 W-35 V1 429.52 450.00 390.26 9.31 380.95 Pass: Major Risk PB W Pad W-36 W-36 V1 384.35 400,00 416.62 6.37 410.25 Pass: Major Risk PB W Pad W-37 W-37 V3 428.74 450,00 445.11 8.13 436.98 Pass: Major Risk PB W Pad W-37 W-37A V3 428.74 450.00 445.11 8.13 436.98 Pass: Major Risk PB W Pad W-38 W-38 V2 337.54 350.00 474.08 6.25 467.83 Pass: Major Risk PB W Pad W-38 W-38A V10 340.02 350.00 474.11 6.18 467.93 Pass: Major Risk PB W Pad W-39 Plan#4 W-39A VO Plan: 428.00 450.00 503.43 9.23 494.21 Pass: Major Risk PB W Pad W-39 W-39 V1 428.00 450.00 503.43 9.07 494.36 Pass: Major Risk PB W Pad W-40 W-40 V1 382.66 400.00 532,69 7,87 524.82 Pass: Major Risk PB W Pad W-42 W-42 V1 391.24 400.00 595.13 6.83 588.30 Pass: Major Risk PB W Pad W-44 W-44 V1 383.49 400.00 656.48 5,95 650.54 Pass: Major Risk Site: PB W Pad ~ Drilling Target Conf.: .. Description: Map Northing: 5962040.00 ft Map Easting: 619560.00 ft Latitude: 70018'17.715N Shape: Circle Target: W-215 Tgt '-'ell: Plan W-215 .-rased on: Planned Program Vertical Depth: 5225.00 ft below Mean Sea Level Local +N/-S: 2637.09 ft Local +E/-W: 7551.83 ft Longitude: 149°01 '53.156W Radius: 200 ft 3000 2900 2800 N ^ 2100 2500 2500 24-00 2300 D D D D D D D D D D D D D D D D (Y) -=I-- Ln LD I m 0- D I I I I I I I m ~ / ~ P 055093 DATE 6/9/2003 I I CHECK NO. 055093 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET 6/9/2003 INV# CK060403M PERMIT TO DRILL FEE H w·).\S JUL 2 B 2003 e THE AlïACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ '·9· "J ''.'" _:.'!i9 CON$oCìDATED COMMERCIAL ACCOUNT "<::0:.. ,"', -.:).:} ,,:,.-...:-:. >:\- .. ALASK.AO 333W7TH SUITE 100... .:. ANCHORAGt;, AK 99501-353.9 . . AMOUNT : . *'*"~**$1 00 :00~j<***~1 NOT VALID AFTER 120 DAYS e ~¡.\~~:~.\.:::;::~.:::~~~::::~~~:::.::.:~:..' ~.:?!~.~.~~:;~.~.::}:\:;D ..... .....~ .... .."".........ø.. _.... ......1 ;.>::;~~:A: .~ -. -7-..': ,~.. ::'.; ~.. ,~·:\~I . : '., ,., . ... .0". ..01: . .. ... .. . ,'",1 ~>: > .:: ::<'(:i~.. .:~:~:::{.\~ :~:;:.~:~::¡~.~:~::~:~.:\::...: ;::>J 1110 5 50 11 3111 I: 0 ~ ~ 20 3 B 11 51: 0 L 2 ? B 11 bill Rev: 07/10/02 C\j ody\templates e e TRANSMITAL LETTER CHECKLIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) Pll..OT (PH) "CLUE" The permit is for a new well bore segment of existing weD Permit No, API No. Production should continue to be reported as a function· of the original API number stated above. BOLE In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing . exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Company BP EXPLORATION (ALASKA) INC Well Name: PRUDHOE BAY UN POL W-215i Program SER Well bore seg D PTD#: 2031310 Field & Pool PRUDHOE BAY. POLARIS OIL - 640160 nitial Classrrype SER 11WINJ GeoArea Unit 11650 On/Off Shore ~ Annular Disposal D Administration Permit fee attaçhe.d, - - - - - - - . Yf;s , , · . - - - - 2 ,Leasf; ,number appropriate Yf;s, - - - - - - - - - -- 3 ,U,nique well, n,arnf; ,a!ld oumb,er , , , , , , ' , ' , ' , , - - - . . - , Yf;s , , · - - - - - - - - - - - - - - - - . - -- 4 WeJUQcated in,a, d,efine.d ,pool , Yes, 5 WeJUQcated pr,oper ,distance, from driJling unitbound,aiy Yes, 6 WeJIIQcatf;d proper distance from other wells Yf;s , . 7 S,utfiçientaçreageaYailable in,drilliog unjt , , , , Yf;s , , 8 If.df;viated. js weJlbQre plaUncJu,ded . , , , , , , , , , , , , Yf;S. 9 ,Operator only: affeçted party, . . . . . . . . , Yes, - - - - - - - - - 10 ,Oper,ator has,appropriate,b.o!ld inJorce , , , , , , , , , , , , , , , , ,Yf;S, , · - - - - - - - - - - - - - - - - - - - - 11 Pf;O'T)it call be issued wjthQut conservation order, Yf;s, - - - - - - - Appr Date 12 Permit call be issued wjthQut administratil¡e,approval , Yf;S. - - - - - - - - - - - - RPC 7/28/2003 13 Can permit be approved before 15-day wait Yes e 14 Well JQc¡;¡t¢C! within area alld.strataauthorized by,lojectioo Ordf;r # (put 10# in, cornrn,e!lts), (For. Yf;S . .ð.IONo. 25 . 15 ,AJI wells.witl1i.nJI4.miLe,area,of reyieW jdf;oUfied (FOr ~ervjCf;w.ellonlY:L . , , . , , . , , , , , , , ,Y,es, , ~O~E"""""",.. . 16 Pre-produced i!ljector; .dl.lratiQn,of pre-pro.dl.lction Less than 3. months (For,selYice well onJy) , , ,NA . 17 ACMP, Fjndjng ,of Con~i~te!lcyhas bee,nj$.sued for this pr,oleçt ......... .NA Engineering 118 C.o!lduct.or s!ring,provided , , . - - - - - - - . Yf;S , 19 Su(face,ca~ing,pJotect~ alLknowll USDWs , - - - - - - - - -- , Yf;S . 20 ,CMT voL adequ,ate, to çi rc,u Late on conductor 8< SUJf.csg . , Yes .ð.de,ql.late exce~s, , 21 CMT voL adequate to tie-in Jong ,stri!lg to,SUG ~g, , - - - - - - - - - - - - -- No, , 22 CMT wil! coyer,aJl know.n,pro,ductiye horizons - - - - - - - - - - -- " " , Yes , - - - - - - - - 23 C,asiog de,sig!lS ad,equa,te for CoT. B&Rel11Jafr.ost - - - - - - " " " " , Yes , 24 ,Mequ<ltetankageoJ re,serye pit. , , , , , , , , , , , , , , , , , , , , , , , , , , Y,es, . ~abors9ES, 25 Jf.a.re-drill~ has, a, 1.0,403 for <lbandOllment bef;O apPJoved , , ....... .NA 26 ,Mequ<ltew.eJlbore ~eparatjo,n,propo~e.d, , , , , , , , , , , , . , , , , , , , , , , , , , , , , Yes, , - - . - - - - - - - - - - - - - - - -- 27 Jf.diver:!er Jequired, doe) jt meet reguJa,tions, , . . , , , , , , , , Yf;s , Appr Date 28 ,DJilliog fJujdRrogram schematic&. equip listadequate , , , , Yf;S , . Max MW9~6 ppg. e WGA 7/29/2003 29 BOPEs.dothey meet regulation , - - - - - - - , , . . Yf;S , 30 BOPE,press ra.tiog appropriate;testto(put PSig Í,n,comments). . . . . , . . . . . . . . . . . . . , Yf;S, TesttoAOQO,psi.MSF'1808psi. 31 C,hoke, manifold compJie~ w/API, RF'-53 (May 84), Yf;s, 32 WQrk will OCC,Ur withoytoperationshutdow.n, . Yf;s - - - - - - 33 I~ pres,ence, of H2S gas, probable. , , . . . . . . . . .. .No 34 Meçha,nicaLcoodjllon of wells within .ð.OR yerified (For servjce well only) . - - - - - - NA. ~o wells jn AOR. Geology 35 Pf;rmit cao be issued wlo hydrogen sulfide meaS,Ure), , . . . . Yf;s , , 36 ,D,ata,PJeseoted on, pote,ntial OveJpres,sl.lre ,zooes, , , , , . . , , , , , , , - - - - - .,... .NA Appr Date 37 ,Sf;Í,smic,analysjs, Qf shaJlow gas,zooes, NA - - - - - - RPC 7/28/2003 38 ,Sf;abed ,conditioo survey,(if Off-shOre) , , , , , .NA - - - - - 39 ,CQntact namelpl1oneJor,weekly progress reports [e)(pIQratoiy ,only] .""""""" ,NA, Geologic Date: Engineering Date PUbIiCV''---> Commissioner: Commissioner: Commissioner ~ {J'Rf 7 / è~ I J 'l