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Home My WebLink About206-072CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Producer 15-02B (PTD #2060720) failed cold TIFL Date:Wednesday, July 16, 2025 9:05:16 AM Attachments:image001.png 15-02B TIO 250716.docx From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, July 16, 2025 9:03 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Bo York <byork@hilcorp.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: RE: UNDER EVALUATION: Producer 15-02B (PTD #2060720) failed cold TIFL Forgot the plots From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, July 16, 2025 8:59 AM To: jim.regg <jim.regg@alaska.gov> Cc: Bo York <byork@hilcorp.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Producer 15-02B (PTD #2060720) failed cold TIFL Mr. Regg, Producer 15-02B (PTD #2060720) IA casing pressure was reported over NOL ~2224 psi on 7/15/25. A subsequent cold TIFL failed with IA fluid level below the OGLV. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Slickline: Set tubing plug 2. Fullbore: MIT-T & CMIT-TxIA 3. Well Integrity: Further action as required. Please call with any questions or concerns. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: AK, D&C Well Integrity Coordinator Sent: Friday, June 20, 2014 4:50 PM To: AK, OPS FS3 OSM <AKOPSFS3OSM@BP.com>; AK, OPS FS3 DS Ops Lead <AKOPSFS3DSOpsLead@bp.com>; AK, D&C Well Services Operations Team Lead <AKDCWellServicesOperationsTeamLead@BP.com>; AK, D&C Wireline Operations Team Lead <AKDCWirelineOperationsTeamLead@BP.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt@BP.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, OPS PCC EOC TL <AKOPSPCCEOCTL@bp.com>; G GPB FS3 Drillsites <ggpbfs3drillsites@BP.com>; Derrick, Mackie <derrgm@BP.com>; AK, OPS FS3 Facility OTL <AKOPSFS3FacilityOTL@bp.com> Cc: AK, D&C DHD Well Integrity Engineer <AKD&CDHDWellIntegri@bp.com>; AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com>; AK, D&C Projects Well Integrity Engineer <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com> Subject: OPERABLE: Producer 15-02B (PTD #2060720) MIT-IA Passed All, Producer 15-02B (PTD #2060720) passed an MIT-IA on 06/19/2014 following gas lift valve work. The passing test confirms two competent barriers in the wellbore. The well is reclassified as Operable. Please use caution while placing the well on production due to fluid packed annuli. Thank you, Jack Disbrow (Alternate: Laurie Climer) BP Alaska - Well Integrity Coordinator Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Sunday, May 18, 2014 8:15 PM To: AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites; Derrick, Mackie; AK, OPS FS3 Facility OTL Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep Subject: NOT OPERABLE: Producer 15-02B (PTD 2060720) Evaluate Well For Tubing x Inner Annulus Communication All, Producer 15-02B (PTD #2060720) has shown signs of possible tubing x inner annulus communication. The plan forward was to set dummy gas lift valves and MIT-IA to prove tubing and production casing integrity. The work to diagnose the communication will not take place before the end of the 28 day Under Evaluation clock due to construction activity on the pad. The well is reclassified as Not Operable until the well can be evaluated. Thank you, Jack Disbrow (Alternate: Laurie Climer) BP Alaska - Well Integrity Coordinator Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Friday, May 02, 2014 5:46 PM To: AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites; Lee, Timothy; Derrick, Mackie Cc: AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, D&C DHD Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep Subject: UNDER EVALUATION: Producer 15-02B (PTD 2060720) Annular communication All, Producer 15-02B (PTD # 2060720) TIO plot indicates potential annular communication. At this time the well has been reclassified as Under Evaluation for additional diagnostics. Plan Forward: 1. DHD: OART 2. Slickline: Caliper, Run DGL and MIT-IA A copy of the Wellbore Schematic and TIO plot have been included for reference. Please call with any questions. Thank you, Laurie Climer (Alternate: Jack Disbrow) BP Alaska - Well Integrity Coordinator WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. New Plugback Esets 6/25/2024 Well Name API Number PTD Number ESet Number Date 1J-127 PB1 50-029-23306-70-00 206-047 T39006 8-22-2006 1J-127 PB2 50-029-23306-71-00 206-047 T39007 8-22-2006 1J-170 PB1 50-029-23310-70-00 206-062 T39008 8-22-2006 1J-170 PB2 50-029-23310-71-00 206-062 T39009 8-22-2006 2K-28AL1 PB1 50-103-20385-71-00 211-134 T39010 10-13-2011 2K-28AL1 PB2 50-103-20385-72-00 211-134 T39011 10-13-2011 PBU 13-27B PB1 50-029-20947-70-00 211-048 T39012 8-11-2011 PBU 13-27B PB2 50-029-20949-71-00 211-048 T39013 8-11-2011 15-02B PB1 50-029-20697-71-00 206-072 T39014 3-7-2008 15-02B PB2 50-029-20697-72-00 206-072 T39015 3-7-2008 CD2-07 PB1 50-103-20472-70-00 203-187 T39016 2-22-2006 CD2-07 PB2 50-103-20472-71-00 203-187 T39017 2-22-2006 E-23C PB1 50-029-21763-71-00 211-053 T39018 9-30-2011 E-23C PB2 50-029-21763-72-00 211-053 T39019 9-30-2011 NS-25 PB1 50-029-23181-70-00 203-166 T39020 3-22-2004 NS-25 PB2 50-029-23181-71-00 203-166 T39021 3-22-2004 OP18-08 PB1 50-029-23449-70-00 211-059 T39022 10-14-2011 OP18-08 PB2 50-029-23449-71-00 211-059 T39023 10-14-2011 15-02B PB1 50-029-20697-71-00 206-072 T39014 3-7-2008 15-02B PB2 50-029-20697-72-00 206-072 T39015 3-7-2008 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:206-072 6.50-029-20697-02-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 12845 10470 8752 9788 12751 10470 8162 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 34 - 114 34 - 114 1530 520 Surface 2645 13-3/8" 33 - 2677 33 - 2677 5380 2670 Intermediate 8764 9-5/8" 31 - 8794 31 - 7341 6870 4760 Production 1353 7" 8657 - 10010 7232 - 8348 7420 5410 Perforation Depth: Measured depth: 10013 - 10044 feet True vertical depth:8350 - 8377 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L-80 28 - 9846 27 - 8210 9788 8162Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Perm Packer Liner 2996 4-1/2" 9840 - 12836 8205 - 8941 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 1153013249 3823465 0 27973 427 486 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Ryan Thompson Ryan.Thompson@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:907-564-5280 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations 5 Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8940 Sundry Number or N/A if C.O. Exempt: N/A No SSSV Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend 5Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028306 PBU 15-02B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Samantha Carlisle at 1:22 pm, Oct 28, 2020 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2020.10.28 11:03:26 -08'00' Bo York MGR29OCT2020 DSR-10/28/2020 RBDMS HEW 10/28/2020 ACTIVITYDATE SUMMARY 9/19/2020 ***WELL S/I ON ARRIVAL*** DRIFT w/ 28.5' x 3-3/8" DUMMY GUNS (Max OD = 3.66"). TAGGED STRADDLE PATCH @ 10760' SLM / 10,774' MD. ***WELL LEFT S/I / E-LINE UP NEXT*** 10/10/2020 T/I/O = 2400/620/100. Temp = SI. TBG FL (E-Line). No AL. TBG FL @ 10,864' (Perforations, 165 bbls). SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:40 10/11/2020 ...Well shut in on arrival... (HES Eline - Plug and Perf) SET NORTHERN SOLUTIONS 4-1/2" CIBP AT 10,470'. ...Job Incomplete, Unit called to Milne. Will return Tuesday to perforate... 10/11/2020 T/I/O=2500/600/50 SI Load Well Pre EL (PROFILE MODIFICATION) Pumped 200 bbls crude down TBG to load for EL perf job. DSO/WSL Notified Valve positions=SV WV SSV closed MV open CVs OTG FWHP=100/600/50 10/15/2020 ***WELL SHUT IN ON ARRIVAL***(adperf) PERFORATE 10013'-10044' WITH 31' x 3-1/8"" HSC LOADED WITH 22.7G GEODYNAMIC RDX CHARGES. CORRELATED TO BAKER HUGHES PNC 3D LOG DATED 07-JAN-2014. REFERENCE LOG DEPTHS: 10018' - 10049'. ***WELL LEFT SHUT IN ON DEPARTURE, TURNED OVER TO DSO*** Daily Report of Well Operations PBU 15-02B STATE OF ALASKA • •ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Mill CIBP Q 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 206-072 3. Address: P.O.Box 196612 Anchorage, Development I7 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20697-02-00 7. Property Designation(Lease Number): ADL 0028306 8. Well Name and Number PBU 15-02B 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 12845 feet Plugs measured feet true vertical 8940 feet Junk12751 measured feet Effective Depth: measured 12759 feet Packer measured 9787 feet true vertical 8945 feet Packer true vertical 8162 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural None Conductor 80 20" 34-114 34-114 1530 520 Surface 2644 13-3/8" 33-2677 33-2677 4930 2670 Intermediate 8762 9-5/8" 31-8794 31-7341 6870 4760 Liner 2996 4-1/2"' 9840-12836 8205-8348 8430 7500 Liner 1353 7" 8657-10010 7232-8348 7420 RECEIVE D Perforation Depth: Measured depth: 10785-12710 feet True vertical depth: 8963-8948 feet .IAN `t 9 2018 �Y Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 28-9846 28-821G CC0 Packers and SSSV(type,measured and 4-1/2"Baker S-3 Perm Packer 9787 8162 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): JAN�p Treatment descriptions including volumes used and final pressure: SCONE° 2 3 iusa 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 829 44596 0 700 1022 Subsequent to operation: Shut-In 50 0 14.Attachments:(required per 20 AAC 25.070.25.071,8 25.283) 15.Well Class after work: Daily Report of Well Operations RI Exploratory ❑ Development EZ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Il Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: Authorized Name: Meixueiro,Pauling Contact Name: Meixueiro,Pauling Authorized Title: Production Engineer- Contact Email: paulina.meixueiro@bp.com Authorized Signature: -%e A, „w Date: 01/p g I 1 8 Contact Phone: +1 907 564 5971 Form 10-404 Revised 04/2017 €f/40, I/7-1--L- 1/}'Z/1 i/ RBDMS (7 J.',,,) 1 1 2:13 Submit Original Only • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report Of Sundry Well Operations (10-404) January 9, 2018 To Whom it May Concern: Attached please find the Report Of Sundry Well Operations for Mill Plug for Well PBU 15-02B, PTD #206-072. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 • • Daily Report of Well Operations PBU 15-02B ACTIVITYDATE SUMMARY CTU#9- 1.75" Coil Job Objective: Mill CIBP MIRU CTU. Make up 2 7/8" Motor and 3.68"concave 5 bladed mill, RIH. 8/6/2017 ..Job in Progress... CTU#9- 1.75" Coil ***Continue from WSR 8/6/17*** Job Objective: Mill CIBP Tagged plug @ 12609'worked extensively trying to see motor work with out luck. POOH to check tools. No issues found. Swap motor and RIH with same BHA. Tag CIBP at 12609' CTMD. Milling very slowly with minimal motor work and high weight set down as mill was dulled. Able to mill CIBP and push to PBTD of 12751' CTMD. FP Well with 50/50 Methanol. ***Job Complete*** 8/7/2017 Fluids Summary Bbls Type 625 Slick 1% KCL 55 50/50 Methanol/Water IFEE= 4-1/16.CM • 4) = 1 SAFETY NOTES: WEI_ANGLE>70.@ 10776' M43_LHEAD FMC ACTUATOR= AXELSON 1 5-02B i •••ORIGINAL WELLBORE NOT SHOWN.** i 0403.ELEV= 63' BP.ELEV= ? iI I:TOP= 3100' Max Ane= 94"@ 12596' I J L 2187' H4-1/2'I-ES X NP,0=3,813" Datum L4)= 10616' Datum 1VD= 13800'SS( GAS LET'MANDRaS i20"CONDUCTOR,94#,H-40,0=19.124- I 79' ST kV 1VD DEV!TYPE VLV LATCH PORT DATE Li 3-318-CSG,72#,L-80 BIC-M.0=12,3472J-1_ 2675' i 4 3153 3151 11 MSG DOW RK 16 08/16117 3 5133 4747 45 WG SO RK 20 08/16/17 1 2 6982 5996 47 HMG MY RK 0 06/28/06 1 18374 7007' 38 'MMG DIN RK 0 06/28)06 Minimum ID = 3.725" @ 9832' 4-112" HES XN NIPPLE Elc. 88 57' —19-5/8- C-2 ZXP LIPID, =826T j II--...„.....: 8676' i---16/8"X r HMG HGR,ID=5,310" 1 i / 9-5/8"MILLOUT )OW(1S-02S) 8794'-8810' 9-5/8"WHPSTOCK(0I3/08/07) H 8794' J. 9767* H4-irr MES X NIP,ID=3.813- 9-5/81EZSV(06/08A37) --L 8816. i AIL 97W 17-X 4-1/2"BKR S-3 PKR, [5-1/2"TBG STUB(06/08/061}- 111366'_ 'Ilp, L9-5/8"CSG,474,L-B0 X0 TO S0095 H 8970' lir 4h, >< '614T•4 9-5/8"CSG,47#,S0095 BIC-44,0=8.681' I-1 10036' 1411 40A.' L 9_111'_ __h H2"'HES X NP,ID=3.813"j "m'CL .• PERFORATION SUMMARY •,4 } w' RfE LOG: TCP ON 06128/06 a •4 9832° H4-1/2"HIES XN NIP,0=3.725" - .• - I •4 ANGLE AT TOP PEW-.66'@ 10785' ..a. •.4 .... .• Note:Refer to Production DB for historical per/data •4 .• •4 //I_ 9340* 1—rx5.ZXP LIP ID=4.410"i ,• SE SPF till bRVAL OpniSqz StIOT SOZ •4 'IPA,•v..v 2-7/r 6 10785-10795 0 04/07/11 ••••0-••• ive•4 4 • -' ri 9346' H4-1/2"INLEG,ID=1958- 2-7/8" 6 6 '° °'10900 0 01/09/14 4•:•:•:•:•4,,04 HNC ••••' •4 -\ I' i 9869' I—7"X 5' LNR HGR, 11090-11140 0 •4 2-1/2" 6 11230-11460 0 06/28/08 **4 . ID=3.980" 2-1/2" 6 11250-12500, 0 06/28/06 i ggsw ji—5'X 4-1/2'X0,ID=3.958- 2-1tr 6 11550-11710 0 06/28/D6 I 2-1/2" 6 11940-12080 0 06/28/06 I 2-1/2' 6 '12110-12220 0 06/28/06 2-1/7' 6 12640-12710 0 06/28/06 I I 1 I I 4-1/2"TBG, 12_6*.L-80 Tal,.0152 bpf,ID=3.958' F— 9846' I I 12751'CTMD —ASH:MILLED WED CP 7"LNR,26*,L-80 BTC-M,.0383 bpf,ID=6.276" H 10010' di (08/07/17) • PErTD H 12751' I , IF ......., •••• Li._1/2 ,12.8#,1-80113T-NI,.0152 bpf,ID=3.958" li—L 12836° 1 DATE REV BY COOMENTS 1 DATE REV BY COMMENTS WILICHOE BAY 1/41" /03/06/82 PM 176 ORIGN4AL COMPLETION i108/21/17 AIG/J1v0 GLV 00(08/16/17) WELL: 15-028 11/08196 MS---'CID"A" 101/09/18 GRC/JMJ CORRECDONS TO LNR DEPTHS — PERMIT No:'2060720 06/30/06 N27E SIDETRACK"3" i API No: 50-029-20697-02 04/15/08 NS/PJC DRLG CRAFT CORRECTIONS SEC 22,111N,R14E, 1141'FTC 8 285'FM_ , . 09/09/14 ‘IGLANU,SET CEP(09/03/14) 08/08/17 Jti#JMD PALLED CIBEYSET FISH(08/07/17) ' BP Exploration(Alaska) ~ • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~~ - 0 ~ ~ Well History File Identifier Organizing (done) RESCAN ~olor Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: ...~„d~ iiumiiiuiiuii DIGITAL DATA ~skettes, No. ~j ^ Other, No/Type: BY: ~ Mar Date: ' Project Proofing BY: Maria Date: ' Scanning Preparation ~ x 30 = BY: Maria _ Date_ ~~ Production Scanning Re,~a.~eeaee iiiimiiiiiuuii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: ~P ~uuu~~~iii~~ii~ ., vn P + ~_ =TOTAL PAGES~~ (Count does not include cover sheet) /~S /s! Stage 1 Page Count from Scanned File: _~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ES NO BY: Maria Date: /3O b ~ lsl Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: o~,„~~~a~„a iuiumiiiiuuu 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA RECEIVED A._,-.SKA OIL AND GAS CONSERVATION COMMISSION Fg 0 6 2014 • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well Li Plug Perforations Li Perforate U Other LIAOGCC Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development Exploratory ❑ a 206-072-0 11 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 A 50-029-20697-02-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028306 . • PBU 15-026 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PPROF " PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth measured a 12845 feet Plugs measured None feet true vertical 8940.46 feet Junk measured None feet Effective Depth measured 12759 feet Packer measured See Attachment feet true vertical 8944.82 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 79 20"91.5#H-40 28-107 28-107 1490 470 Surface 2644 13-3/8"72#L-80 28-2672 28-2671.92 4930 2670 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet True Vertical depth See Attachment feet SCANNED MAY 2 9 2014 Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 28-9846 28-8210.53 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): RBDMS° MAY 17 2014 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 366 36152 0 0 935 Subsequent to operation: 216 29547 4 0 918 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Q I Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil . Q Gas LJ WDSPL! GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUCG 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Nita Summerhays Email Nita.Summerhaysabp.com Printed Name Nita Summerhays Title Data Coordinator _ Sign "f 4iii7 • i��l.•�.....— Phone 564-4035 Date 2/6/2014 / F 5/7°PPI- Form 10-404 Revised 10/2012 /0,7 Submit Original Only Daily Report of Well Operations ADL0028306 ACTIVITYDATE ,.� °; -,� r -• 01 1= i• S Job Objective: PPROF/RPM/Set CIBP&Addperf/N2 Lift MIRU. MU WFD MHA w/3.70"barbell nozzle& RIH. Drifted to PBTD painted a flag 30' off bottom. POOH. 1/5/2014 **"Job in Progress*** 'B&C Coil 1.75"CT(Cl V=37.1 bbls) Job Objective: PPROF/RPM/Set CIBP&Addperf/N2 Lift RIH w/SLB PPROF logging tools . Log up&down passes @ 40/60/80 fpm from flag @ 12697' CTM to 10700'. Perform stop counts(see log for details). POOH. RIH w/ Baker RPM logging tools fluid pack well w/1% KCL 290 bbls. 1/6/2014 ***Job in progress*** B&C Coil 1./5"CT(Cl V=3/.1 bbls) Job Objective: PPROF/RPM/Set CIBP&Addperf/N2 Lift RIH w/BKR RPM tool and make 2 base line passes with 1%KCI from flag @ 12712'up to 9950'at 20fpm. Displace 30bbls of borax into the perfs and log 2 borax passes from flag @ 12712' up to 10500'at 20fpm. Paint two flags while logging up for plug setting depths. POOH displacing borax into the formation w/1% KCI. FP backside of well w/ 18bbls of 60/40 methanol.APE decided not to run CIBP perforate as per program. RIH #1 w/25'2.88"guns-6 spf-60 deg-2906 PJ HMX 1/7/2014 ***Job continued*** B&C Coil 1.75"CT-(C1 V=37.1 bbls) Job Objective: PPROF/RPM/Set CIBP&Addperf/N2 Lift RIH#1 w/25'2.88"guns-6 spf-60 deg-2906 PJ HMX top shot 11115'- 11140'. RIH#2 w/30'2.88"guns-6 spf-60 deg-2906 PJ HMX top shot 10870'- 10900'. MU PDS GR/CCL logging toolstring and RIH. Log up from 11600' up to 9600' at 60fpm. POOH. Process data, +20ft correction. 1/8/2014 RIH#3 w/25'2.88"guns-6 spf-60 deg-2906 PJ HMX '***Job continued*** B&C Coil 1.Tb"CT(CTV=37.1 bbls) Job Objective: PPROF/RPM/Set CIBP&Addperf/N2 Lift RIH#3 w/25'2.88"guns-6 spf-60 deg-2906 PJ HMX top shot 11090'- 11115'. RIH#4 w/25'2.88"guns-6 spf-60 deg-2906 PJ HMX top shot 10850'- 10875'. POOH. Perform weekly BOP test. Stab back onto well w/JSN for N2 lift. 1/9/2014 ***Job continued*** B&C Coil 1.T5"CT(CTV=37.1 bbls) Job Objective: PPROF/RPM/Set CIBP&Addperf/N2 Lift Rig up and PT N2 pumpers. RIH w/2.25" DJN to 6000'stopping every 1000'on the way down pumping 600 scfm. Stopped at 6000'and let well stabilize. SI N2 and monitor production. 1/10/2014 *** Job continued *** B&C Coil 1.75"CT(Cl V=37.1 bbls) Job Objective: PPROF/RPM/Set CIBP&Addperf/N2 Lift Continue monitor production w/out N2. POOH once well stabilized. Notified operator of well status. 1/11/2014 *** Job Complete *** FLUIDS PUMPED BBLS 287 60/40 METH 396 1% KCL 196 BORAX 879 TOTAL a) N l6 M v- Lf) 0) O C 7 r- Ns N- L N Cfl V V N 10 N- Cn p_ Cfl In Cfl O N N N 00 CO CA f- d CO CO cc CC) CA CA O O N CA CC) - p CA CA O) CA CA CA co CA O) co CD 0) 00 00 00 00 cc 00 0000 CO CO 0 W Z W a a J U O 0 Y YO Cfl N- v- N LU CO 00 O) N 0 0 W 0' w L `. O CO V N- V 00 (h N c- N N d d C/) Z 0- M N L (O O ti c W (7 2 C7 a) (C) 00 00 CO CA O CA CD 00 N- N- LU J W W CD CD O 0) 0) Cl) CA O) 0 Cr CA o3 (A 0 -I -1 J 0 J 00 00 00 cc 00 00 00 00 00 00 = 0 a W a LJ Q OJ Q 0 cn u) cn cn cn a) N m • O LU O LU 0 0 0 0 0 0 O C) N- 1 O V (O Cp N O r a N- CD 00 0) - N- O N In N- 0 0 0 0 0 '- N N N N CD N co a) _ 2 0 0 cn V 0 V)Hv~) can CJI) can RN UPCD Q OD a N0 O ~ pCO O LUO0 0 0 0 O _ d 0O O N- r2. C)) � () Ln 0 O Q CD 0 0 0 0 00 0 N N N N 03 0 L N 2 a) a. a 0 U c • LL LL LC_ W LL LL W W W W W W 0- 0- 0- 0_ 0_ 0_ W W W W W W O 0 0 Q Q Q Q 0_ a 0_ 0_ d a 0 0 a) a m N ? o ,r ,r ,r `T ,r00000 o - L c 0 0 0 0 0 0 0 C) C) C) 0 O J Z • N N N N N N N N N N N a- Q W W Cii00 00 a0 OD cc a0 w Ui N N U C N N N N N N C7 U W W a w a. Cr c- c- O CO CO cc cc CO 0 J J DD a' a O a J 0 0 w w m cn cn a a) E z 03 07 00 00 00 00 CO 00 00 m 00 00 N N N N N N N N N N N N 0 0 0 0 0 0 0 0 0 0 0 O N i i i i i i i i i CO O a N a' a IC) l!) In In L(7 L(1 In L() L() L() a 0 J a O W Cl- m w LI cn cn a m Q o 0 0 o 0 0 0 - (o °or� o • f— 1.0 N I� U N 0 0 0 0 0 0 0 • N Nr CO - m CO CO CO CO O CO CO N CO O O N C)) LC) O I� O N co 0 ti M 0 V co CO N 00 00 N- aO N OO H (0 CO CO CO CO CO CO cd nj co 0o N M O N co N N N N �+ CO N- C O 0 CO f co N CO O O 00 O O cc cc � r r C) 'W Q 2 • Q 00 cc o 4- to CD CO 00 C) (V N (O cc N O) N N C Q Q � J 1- Q 0 coo � 6) coco C) O J J J C 0 •N N �? *kN *kr` � v °) `nCr) 7 rn s CA O (o 0 v CO CO C N- CO O 0) O O CO d M CO — N O _O O 011— HILL) N D » U � Cl L O 0 LL Z V ZLuwOOCC O Z Z aCt D D C. J J 0- 0- U) F- Packers and SSV's Attachment ADL0028306 SW Name Type MD TVD Depscription 15-02B PACKER 8657 7165.16 7" Baker ZXP Mech Top Packer 15-02B PACKER 9788 8095.85 4-1/2" Baker S-3 Packer 15-02B PACKER 9849 8146.52 4-1/2" Baker ZXP Mech Set LT Pac TREE=, 4-1/16"CAN WELLHEAD= FMC SAFETY NOTES: W EL ANGLE>70°@ 10776' ACTUATOR= AXELSON 15.0 2 B ***ORIGINAL WELLBORE NOT SHOWN'** KB ELEV= 63• BF.ELEV= KOP= 3100' Mex Angle= 94°@ 12596' ' ' 2187' H4-1/2"FES X NP,D=3.813" Datum MD= 10616' Datum TVD= 8800'SS 20"CONDUCTOR,94#,11-40,D=19.124" 79' / GAS LFT MANDRELS ST M3 ND DEV TYPE VLV LATCH PORT DATE 13-3/8"CSG,72#,L-80 BTC-M,D=12.347' — 2675' 4 3153 3151 11 WAG DOME RK 16 7/6/2006 1A 3 5133 4747 45 ?MG SO RK 20 7/6/2006 2 6982 5996 47 MAG DMY RK 0 06/28/06 Minimum ID = 3.725" @ 9832' 1 8374 7007 38 MM3 DMY RK 0 06/28/06 4-112" HES XN NIPPLE 8657' H9-5/8"X 7"C-2 ZXP LTP,ID=6.260" 8675' —I 9-518-X 7^HMC HGR,D=6.310- / 9-5/8"MN-LOUT WIDOW(15-02B) 8794' 8810' 9-5/8"WHPSTOCK(06/08/07) 8794' 1 9767' H4-1/2"HES X NP,D=3.813" 9-5/8"EZSV(06/08/07) H 8815' 9788" 7"X 4-1/2'BKR S-3 PKR, 5-1/2"TBG STUB(06/08/06) _I 8965' J ' 1D=3.870" 9-5/8"CSG,47#,L-80 XO TO SOO95 H 8970' \ —essasam ;tk 9-5/8"CSG,47#,SOO95 BTC-M,D=8.681^ H 10036' ��'A ' 9811' H4-1/2"HES X NP,D=3.813" PERFORATION SUfv /tARY m 04i REF • LOG: TCP ON 06/28/06 *•4 (1c 9832' H4-1/2"HES XN NNP,D=3.725^ ANGLE AT TOP PERF:68°@ 10785' ■0-4 r Note:Refer to Production 013 for historical pert data - 44 9846' —{4-112"WLEG,D=3.958" SEE SPF INTERVAL Opn/Sqz SHOT SQZ iii 2-7/8" 6 10785-10795 0 04/07/11 �•4 " 9849' -17^X 5"ZXP LTP D=4.410" 2-7/8" 6 10850-10900 0 01/09/14 0,4I i 4 9869' (—7^X 5"HMC LNNR HGR, 2-7/8" 6 11090-11140 0 01/09/14 i " • •,4 2-1/2" 6 11230-11460 0 06/28/06 ••�•�4�•�1 ` 0=3.980" 2-1/2" 6 11250 12500 0 06/28/06 ..•••••• 04 . •• 004 I 9886' 5"X 4-112"X0,D=3.958" 2-1/2" 6 11550-11710 0 06/28/06 *.•,,• 0,•4 2-1/2" 6 11940-12080 0 06/28/06 iii • 2-1/2" 6 12110-12220 0 06/28/06 •04 ' ►!4 2-1/2" 6 12640-12710 0 06/28/06 ' 4-1/2"TBG,12.6#,L-80 TCI,.0152 bpf,ID=3.958" --I 9846' , 1 7"LN2,26#,L-80 BTC-M,.0383 bpf,D=6.276" I— 10010' ' PBTD --1 12759' ••••4 i•i�i�i 4-1/2"LNR,12.6#,L-80 ET-M,.0152 bpf,D=3.958' --+ 12845' DATE REV BY COMMITS CATS REV BY COMENTS FRUDHOEBAY UNT 03/06/82 PKR 176 ORIGINAL COMPLETION 01/15/14 IH1/JM) AOFERFS(01/09/14) WELL: 15-026 11/08/96 N3S CTO"A" PERMIT No: 2060720 06/30/06 N27E SIDETRACK"B" API No: 50-029-20697-02 07/06/06 DRF/PAG GLV C/O SEC 22,T11 N,R14E,1141'FTN-&285'F WL 04/15/08 NS/PJC ORLG(RAFT CORRECTIONS 04/28/11 JMC/PJC ADPERFS(04/07/11) BP Exploration(Alaska) Schla,mberger RECEIVED No. 5769 Alaska Data & Consulting Services 'UL ? 6 2011 Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Stephanie Pacillo & Gas Cons. CommisSion 333 West 7th Ave, Suite 100 Anchorage Anchorage, AK 99501 Well Job # Log Description Date BL Color CD H -17A BLPO -00119 PPROF W GHOST 10- Jul -11 1 1 14 -04A AV1P -00093 LEAK DETECTION LOG 9- Jul -11 1 1 E -01A BLPO -00121 PPROF W GHOST 12- Jul -11 1 1 III MPB -50 BCRJ -00096 RST WFL LOG 16- Jul -11 1 1 H -14B BD88 -00113 PPROF WI DEFT & GHOST 2- Jun -11 1 1 OWDW -SW AV1P -00091 RST WFL LOG 16- Jul -11 1 1 06 -02A BL65 -00027 LDWG EDIT OF MCNL 4- May -11 1 1 ,lot,- t 7215 -02B BJOH -00016 LDWG EDIT OF RST 1- Apr -11 1 ' 1 - [ '/ ' P2 -41 BJOH -00020 _ LDWG EDIT OF RST _ 11- Apr -11 1 1 _ W -223 IBCRJ -00086 LDWG EDIT OF USIT 18- May -11 NIA 1 W -202 BMSA -00005 LDWG EDIT OF USIT 30- Jan -11 NIA 1 06 -08A BCRD -00089 LDWG EDIT OF RST 6- Mar -11 1 1 0 - - PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Erploiatiori (Alaska) Inc.. Alaska Data & Consulting Services P Petrotechnical Data Center L.R2 1 2525 Gambell Street, Suite 400 900 E Benson Blvd { t Anchorage, AK 99503 -2838 I -'tVIV .ra -} 1 I J , .t ( Ctt'l a 7 1 STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ WaiverD Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate El Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development IO Exploratory ❑ tg 206 -0720 3. Address: P.O. Box 196612 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99519 -6612 — 50- 029 - 20697 -02 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028306 - PBU 15 -02B 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 12845 feet Plugs (measured) None feet true vertical 8940.46 feet Junk (measured) None feet Effective Depth measured 12759 feet Packer (measured) 8657 9788 9849 feet true vertical 8944.82 feet (true vertical) 7232 8162 8213 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 20" 91.5# H -40 28 - 107 28 - 107 1490 470 Surface 2644' 13 -3/8" 72# L -80 28 - 2672 28 - 2672 5380 2670 Production 8785' 9 -5/8" 47# L -80 25 - 8810 25 - 7354 6870 4760 Liner 1353' 7" 26# L -80 8657 - 10010 7231 - 8348 7240 5410 Liner 3001' 4 -1/2" 12.6# L -80 9844 - 12845 8209 - 8940 8430 7500 Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# ;,a' 28 - 9846 28 - 8211 Packers and SSSV (type, measured and true vertical depth) 7" C -2 ZXP LTP 8657 7232 4 -1/2" BKR S -3 PKR 9788 8162 5" ZXP LTP 9849 8213 E! ' 5. 12. Stimulation or cement squeeze summary: Intervals treated (measured): WO 'w?` 2 4 ,;O1 Treatment descriptions including volumes used and final pressure: 10,s1:2 Gil & Giq 13. Representative Daily Ft EW: • uction or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 334 22,028 0 992 Subsequent to operation: 717 23,715 69 933 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development El • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil , El Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Na e Joe astufk 1 i 1 Title Petrotechnical Data Technologist Signatur: Phone 564 -4091 Date 5/23/2011 - • BDMS MAY 2 5 '2011 � ^S• if S ubmit Ori final Only Form 10 -404 Revised 10/2010 J •, 9 y 15-02B 206 -072 . PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 15 -02B 6/28/06 PER 11,230. 11,460. 8,995.86 8,997.9 15 -02B 6/28/06 PER 11,550. 11,710. 8,998.3 8,992.53 15 -02B 6/28/06 PER 11,940. 12,080. 8,985.28 8,978.17 15 -02B 6/28/06 PER 12,110. 12,220. 8,977.19 8,973.6 15 -02B 6/28/06 PER 12,250. 12,500. 8,972.74 8,959.71 15 -02B 6/28/06 PER 12,640. 12,710. 8,951.72 8,947.54 15 -02B 4/7/11 APF 10,785. 10,795. 8,963.1 8,966.76 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET • FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • 15 -02B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 4/6/2011 ** *WELL SHUT -IN ON ARRIVAL" * *(E -LINE PERF) INITIAL T /I /O = 0/450/0 RIGUP E -LINE WHE AND SURFACE CHECK TOOLS. PT THEN ARM AND STAB BACK ON. ** *JOB CONTINUED ON 7- APRIL - 2011 * ** 3 i 4/7/2011' ** *JOB CONTINUED FROM 6-APR-2011'(E-LINE PERF) , RIH WITH MH- 22(5X3)/ERS/1- 11/16" WEIGHT /CCL /2 -7/8" GUN: OAL = 23', OD = 2-1 7/8 ", WEIGHT = 300 LB, OD = 2.88 ". CORRELATED TO MEMORY PRODUCTION 'PROFILE DATED 25 -NOV -2008. PERFORATE INTERVAL FROM 10785'- 10795' WITH 2 -7/8" HSD, 6 SPF PJ2906 GUN. CCL TO TS = 3.5', CCL STOP ' 110781.5'. GOOD INDICATION OF FIRE. POOH. FINAL VALVES: WING CLOSED, MASTER OPEN, SSV CLOSED, SWAB CLOSED. RDMO AND HANDOVER TO DSO. FINAL T /I/O= 0/400/0 ** *JOB COMPLETED * ** FLUIDS PUMPED BBLS 2 DIESEL 2 TOTAL TREE =, " 4- 1/16" CIW • WELLHEAD = FMC 15 0 2 B SAFETY N: WEL ANGLE> 70° @ 10776' ACTUATOR = AXELSON' * * *ORIGINA ELLBORE NOT SHOWN * ** KB. ELEV = 63' BF. ^ELEV = -- __..._ -? I > KOP = 3100' Max Angle = 94° @ 12596' ' ' L1 2187' H 4 -1/2" HES X NIP, ID = 3.813" I Datum MD = 10616' Datum TV D = 8800' SS GAS LIFT MANDRELS 120" CONDUCTOR, 94 #, H -40, ID = 19.124" I 79' ST MD 1VD DEV TYPE VLV LATCH PORT DATE 13 -3/8" CSG, 72 #, L -80 BTC-M, ID = 12.347" 2675' 4 3153 3151 11 MMG DOME RK 16 7/6/2006 H 3 5133 4747 45 MMG SO RK 20 7/6/2006 E. 2 6982 5996 47 MMG DMY RK 0 06/28/06 1 8374 7007 38 MMG DMY RK 0 06/28/06 Minimum ID = 3.725" @ 9832' ' 4 -1/2" HES XN NIPPLE J ( 8657' H 9 -5/8" X 7" C-2 ZXP LTP, ID = 6.260" 8675' H9-5/8" X 7" HMC HGR, ID = 6.310" I 9 -5/8" MILLOUT WINDOW (15 - 02B) 8794' - 8810' I 19-5/8" WHIPSTOCK (06/08/07) 1—' 8794' ' t\ 9767' 1- 14 -1/2" HES X NIP, ID = 3.813" 1 9 -5/8" EZSV (06/08/07) H 8815' r rh,q q p 1 9788' 1— 7" X 4-112" BKR S-3 PKR, 15-1/2" TBG STUB (06 /08 /06) 1-1 8965' •) ID = 3.870" 19 -5/8" CSG, 47 #, L -80 XO TO S0095 H 8970' 9 -5/8" CSG, 47 #, S0095 BTC-M, ID = 8.681" H 10036' 4 4 ... 1 9811' 1-14-1/2" HES X NIP, ID = 3.813" I M PERFORATION SUMMARY REF LOG: TCP ON 06/28/06 1 14 9832' J-14-1/2" HES XN NIP, ID = 3.725" f • MP ANGLE AT TOP PERF: 68' @ 11230' 11•46 � Note: Refer to Production DB for historical perf data - %i •• 9846' 1-14-1/2" WLEG, ID = 3.958" SIZE SPF INTERVAL Opn /Sqz DATE / _ �i� 2 -7/8" 6 10785 - 10795 0 04/07/11 t/ %i s 9849' (--J 7" X 5" ZXP LTP, ID = 4.410" , 2 -1/2" 6 11230 - 11460 0 06/28/06 A i 2 -1/2" 6 11250 - 12500 0 06/28/06 1 • 1 9869' I— 7" X 5" HMC LNR HGR, 2-1/2" 6 11550 - 11710 0 06/28/06 �: �� . � ID = 3.980" 2 -1/2" 6 11940 - 12080 0 06/28/06 � * * ;•• ••••!i , • 4 9886' 1-15" X 4 -1/2" XO, ID = 3.958" 1 2-1/2" 6 12110 12220 0 06/28/06 •' . • 2 -1/2" 6 12640 - 12710 0 06/28/06 0 1 0 1 I 4 -1/2" TBG, 12.6 #, L -80 TCII, .0152 bpf, ID = 3.958" I--{ 9846' 1 1 17" LNR, 26 #, L -80 BTC-M, .0383 bpf, ID = 6.276" 1-1 10010' 1 1 I PBTD 1-I 12759' j i • • • i•00i 14-1/2" LNR, 12.6 #, L -80 IBT -M, .0152 bpf, ID = 3.958" H 12845' ∎ ■ ' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/06/82 PKR 176 ORIGINAL COMPLETION WELL: 15 - 02B 11/08196 N3S CTD "A" PERMIT No: I t060720 06/30/06 N27E SIDETRACK "B" API No: 50 - 029 - 20697 - 07 /06 /06 DRF /PAG GLV C/O SEC 22, T11 N, R14E, 1141' FNL & 285' FWL 04/15/08 NS /PJC DRLG DRAFT CORRECTIONS 04/28/11 JMC/PJC ADPERFS (04/07/11) BP Exploration (Alaska) t~ . ~~ ~~ ~. _ ~ :: .~'. , r ;'. ' ~ f ~ F':.' tr ~, r t, ~~V :d. . ~ MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 15 Dear Mr. Maunder, °24 ~ ~ ~~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 15 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-15 Data' 01/05/10 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 15-01 B 2042570 50029206960200- NA Sealed NA 15-026 2060720 50029206970200 NA Sealed NA 15-03 1820300 50029207220000 NA Sealed NA 15-04B 2071380 50029207260200 NA Sealed NA 15-05A 1950340 50029207310100 NA Sealed NA 15-06A 1982540 50029207420100 NA 6.7 NA 40.8 11/7/2009 15-07C 2030970 50029211660300 NA 5 NA 34.0 11 /10/2009 15-08C 2050050 50029211800300 NA 6.5 NA 45.9 11/28/2009 15-09A 1931380 50029212010100 NA 0.9 NA 5.1 11/11/2009 15-10A 1880850 50029205010100 NA Sealed NA 15-118 2041460 50029206530200 NA Sealed NA 15-126 2060870 50029206650200 NA Sealed NA 15-13A 1991240 50029206450100 NA Sealed NA 15-14A 2042220 50029206820100 NA Sealed NA 15-15C 2081820 50029206910300 NA Sealed NA 15-16A 2011920 50029211150100 NA 0.3 NA 3.4 11/7/2009 15-17 1840890 50029211260000 NA 14.7 NA 132.6 12/4/2009 15-18A 2080830 50029222740100 NA 0.4 NA 1.7 11/11/2009 15-19A 1990990 50029218290100 NA surface NA 15-20C 2050930 50029211330300 NA 17 NA 120.7 12/2/2009 15-21A 1990290 50029205030100 NA Sealed NA 15-22 1800970 50029205090000 NA Sealed NA 15-23A 2031110 50029222250100 NA 0.7 NA 3.4 10!712009 15-24 1911280 50029222230000 NA 1.3 NA 10.2 10/7/2009 15-25B 2080240 50029218420200 NA 0.8 NA 6.8 11/12/2009 15-26B 2041590 50029222350200 NA 0.3 NA 1.7 10/8/2009 15-27 1920060 50029222430000 NA 0.3 NA 1.7 10!812009 15-28A 2031240 50029222470100 NA 0.5 NA 8.5 11!9/2009 15-296 2090380 50029222590200 NA 0.1 NA 1.7 11/10/2009 15-30A 2020890 50029222820100 NA 0.8 NA 5.1 11/11/2009 15-316 2050860 50029222850200 NA 1.2 NA 3.4 11/11/2009 15-32A 2011840 50029224620100 NA 1.5 NA 10.2 10/7/2009 15-33B 2031940 50029224480200 NA 1.6 NA 10.2 11/29/2009 15-34A 2001370 50029224740100 NA 1.4 NA 8.5 11/10/2009 15-35 1940880 50029224880000 NA 1.8 NA 15.3 11/10/2009 15-366 2060730 50029224800200 NA 1 NA 5.1 11/10/2009 15-376 2040190 50029224850200 NA 1.3 NA 10.2 11/9/2009 15-38A 2030160 50029224960100 NA Sealed NA 15-39A 2060860 50029225030100 NA 0.3 NA 1.7 11 /9/2009 15-40A 1980980 50029225110100 NA 1 NA 5.1 11/9/2009 15-416 2011460 50029224920200 NA 1.2 NA 6.8 11/9/2009 15-428 2090730 50029226240200 NA 1.5 NA 11.9 11/11/2009 15-44 1961100 50029226830000 NA 3.5 NA 30.6 12/17/2009 15-45B 2071790 50029226710200 NA 1.7 NA 11.9 11/8/2009 15-46 2041030 50029226650000 NA 1.9 NA 17.0 11/9/2009 15-47 1951740 50029226170000 NA 1.5 NA 10.2 10/9/2009 15-486 2051660 50029226350200 NA 1.2 NA 10.2 10/8/2009 15-496 2090640 50029226510200 NA 7.3 NA 51.0 11/8/2009 12/08/08 .~. Sch(umherger NO. 4995 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 , ~;,~,,~ ~i~,, ~~,,~~ ~ "~ ~> F• ., Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 +~:• i..,i"C~D3:".~+ '-~ ~ ~ ~. ~ ~~~~ Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Woll _Inl. it 1 .... new.- .,... R-03A 4994 INJECTION PROFILE (REVISED) 10/08/08 1 1 13-23A 4994 INJECTION PROFILE 10/21/08 1 01-26A 4994 SCMT 11/13/08 1 1 D-29 4994 USIT 10/19/08 1 1 15-026 4994 MEM PROD PROFILE 11/25/08 1 1 H-05A 4994 MEM PROD & INJ PROFILE 11/20/08 1 1 E-32A 4994 SCMT ( 11/04/08 1 1 12-17 4994 PRODUCTION LOG Q C-J 11/04/08 1 1 P2-41 4994 PRODUCTION LOG 11/07/08 1 1 1••29/M-25 4994 PRODUCTION LOG (p - 11/04/08 1 1 MPC-05A 4994 MEM LDL 11/15/08 1 1 L-114A 4994 USIT ;. r•. (( s 11/03/08 1 1 A-07 4994 PRODUCTION PROFILE ~ ( ~} 11/27/08 1 1 07-18 4994 INJECTION PROFILE ~- 12/02/08 1 1 15-126 4994 MEM PROD PROFILE - (,p ^ ~ 11/27/Og 1 1 4-40/P-43 4994 MEM LDL i9 - `'~' '.~ •• 11/26/08 1 1 N-14B 4994 MCNL -(~'~rJ ~ 09/20/08 1 1 01-21A 4994 MCNL 09/29!08 1 1 E-29A 4994 MCNL _ 09/01/08 1 1 PI FACE eeknlnwl Gnr_c ee rooT ev clr_w u.~r_ n.~n e~r• •~.••.•.... ------ ••-••-•-----.--••~ ..wrn • r • v.~w..n.~a r+nv IIGI Vnl\tl\VI VI\G VVf i CNlil'1 1 V: BP Exploration (Alaska) Ina Petrotechnicaf Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503•~8~8 ATTN: Beth II'' Received by:~ ~ h a o • J ~C s o ~w~ DATA SUBMITTAL COMPLIANCE REPORT 6/25/2008 Permit to Drill 2060720 Well Name/No. PRUDHOE BAY UNIT 15-02B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20697-02-00 MD 12845 TVD 8940 Completion Date 6/30/2006 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / GR, GR, MWD GR /DEN / NEU Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Type Med/Frmt Number Name Scale Media No (data taken from Logs Portion of Master Well Data Maint Interval OH / Start Stop CH Received Comments D Asc Directional Survey 33 12845 Open 7/19/2006 D D Asc Directional Survey 33 11036 Open 7/19/2006 PB 1 D D Asc Directional Survey 33 11083 Open 7/19/2006 PB 2 15499 LIS Verification 8492 12845 Open 10/3/2007 LIS Veri, GR, ROP, FET, NCNT, FCNT, NPHI, RHOB,DRHO C Lis 15499 Induction/Resistivity 8492 12845 Open 10/3/2007 LIS Veri, GR, ROP, FET, NCNT, FCNT, NPHI, RHOB, DRHO w/Tap graphics pt 15500 LIS Verification 8492 11036 Open 10/3/2007 PB1 LIS Veri,FET, GR, ROP, RPD C Lis 15500 Induction/Resistivity 8492 11036 Open 10/3/2007 P61 LIS Veri,FET, GR, ROP, RPD w/Graphics pt 15501 LIS Verification 8492 11001 Open 10/3/2007 P62 LIS Veri, GR, ROP, RPD, FET, FCNT, NCNT, NPHI, RHOB, DRHO ,QED C Lis 15501 Induction/Resistivity 8492 11001 Open 10/3/2007 P62 LIS Veri, GR, ROP, RPD, FET, FCNT, NCNT, NPHI, RHOB, DRHO w/graphics og Induction/Resistivity 25 Col 8794 12845 Open 3/7/2008 MD ROP, DGR, EWR, CTN, ALD, 24-Jun-2006 Log Induction/Resistivity 25 Col 7341 8940 Open 3/7/2008 TVD DGR, EWR, CTN, ~ ALD, 24-Jun-2006 i ~og Induction/Resistivity 25 Col 8480 11036 Open 3/7/2008 P61 MD ROP, DGR, i EWR, 17Jun-2006 1~bg Induction/Resistivity 25 Col 7091 8994 Open 3/7/2008 PB1 TVD, DGR, EWR, `~' 17Jun-2006 --- _ _- DATA SUBMITTAL COMPLIANCE REPORT 6/25/2008 Permit to Drill 2060720 Well Name/No. PRUDHOE BAY UNIT 15-02B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20697-02-00 MD 12845 TVD 8940 Completion Date 6/30/2006 Completion Status 1-OIL Current Status 1-OIL UIC N ~g Induction/Resistivity 25 Col 8480 11083 Open 3/7/2008 PB2 MD ROP, DGR, ~' EWR, CNT, ALD 17Jun- 2006 og InductionlResistivity 25 Col 7091 9162 Open 3/7/2008 PB2 TVD ROP, DGR, EWR, CNT, ALD 17Jun- 2006 ED C 15999 See Notes 0 0 3/7/2008 TVD and MD graphics Logs w/PB1 and PB2 in ~ CGM, PDF and EMF graphics JVell Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION ~ Well Cored? Y9~ Daily History Received? N Chips Received? Y / N Formation Tops ~N Analysis Y / N Received? Comments: • Compliance Reviewed By: Date: WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs : 15-02B+PB1+PB2 r^\ 1_J February 27, 2008 AK-MW-4429508 15-02B+PB 1+pB2: 2" x 5" MD TC Logs: 1 Color Log 50-029-20697-02,71,72 2" x 5" TVD TC Logs: 1 Color Log 50-029-20697-02, 71,72 Digital Log Images: 1 CD Rom 50-029-20697-02,71,72 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center, MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 __ Date:.., , , _ Signed ~;n ; ~~-v~2 ~ cs~~~ a • i WELL LOG TRANSMITTAL To: State of Alaska October 1, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 15-02B PB1 AK-MW-4429508 1 LDWG formatted CD rom with verification listing. API#: 50-029-20697-71 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage,; Alaska _99518 ;- •r Date: BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 r Signed: ~ ~~ ao~' b~ ~ ~ WELL LOG TRANSMITTAL To: State of Alaska October 1, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 15-02B PB2 AK-MW-4429508 1 LDWG formatted CD rom with verification listing. API#: 50-029-20697-72 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Da.;~e BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: ~v~_a~~ ~~~~~ WELL LOG TRANSMITTAL To: State of Alaska September 28, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 15-02B AK-MW-4429508 I LDWG formatted CD rom with verification listing. API#: 50-029-20697-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date ~' - BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 d Signed: r~DCo ~ ~°~2 ~ r s vg9 • • 06-Jul-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 15-02B PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. ~ ~ f ~ ~.- Tie-on Survey: 8,778.50' MD Window /Kickoff Survey: 10,980.21' MD (if applicable) Projected Survey: 11,036.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ ~ Si ned D 9 Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~1a3~ ~~ ~-~~ ~. • • 06-Jul-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 15-02B PB2 Dear Dear Sir/Madam: Enclosed is one disk with the'~.PTT and *.PDF files. Tie-on Survey: 10,602.27' MD ~ Window /Kickoff Survey: 11,036.70' MD (if applicable) Projected Survey: 11,083.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 a Date Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~ ~ - u7 ~. • • 06-Jul-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 15-02B Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 10,507.50' MD 3 ~~ ~ ~ ~ z ~ ~~~ Window /Kickoff Survey: 12,799.13' MD (if applicable) Projected Survey: 12,845.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN.EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 , Date ~~.L°i. /6~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) 1~t~-viz STATE OF ALASKA ALASKA~IL AND GAS CONSERVATION COMMISSION RECEIVED JUL 2 4 2006 WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska Oii & bas Cons. Commission 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoAACZS.,os zoAACZS.,,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1b. Well Class: Ot'8g@ ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 6/30/2006 12. Permit to Drill Number 206-072 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 6/11/2006 13. API Number 50-029-20697-02-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 6/23/2006 14. Well Name and Number: PBU 15-026 1441 FNL, 285 FWL, SEC. 22, T11 N, R14E, UM Top of Productive Horizon: 3753' FNL, 3642' FEL, SEC. 21, T11N, R14E, UM 8. KB Elevation (ft): 66.5' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 1938' FNL, 4518' FEL, SEC. 21, T11N, R14E, UM 9. Plug Back Depth (MD+TVD) 12759 + 8945 Ft Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 676223 y- 5960047 Zone- ASP4 10. Total Depth (MD+TVD) 12845 + 8940 Ft 16. Property Designation: ADL 028306 TPI: x- 672356 y- 5957645 Zone- ASP4 Total Depth: x- 671434 y- 5959439 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' A ( pprox.) 21. Logs Run: MWD DIR / GR, GR, MWD GR /DEN / NEU 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 79' Surface 79' 30" 1902 sx Poleset 13-3/8" 72# L-80 Surface 2675' Surface 2675' 17-1/2" 3000 sx Fondu 400 sx Permafrost 9-5/8" 47# L-80/SO 5 Surface Surface 7341' 12-1/4" 500 sx I s 'G' 7" 26# L-80 8647' 10010' 7224' 8348' 8-1 /2" 280 sx Class 'G' 4-1/2" 12.6# L-80 9849' 12845' 8213' 8940' 6-1l8" 503 sx Class'G' 23. Perforations open to Production (MD + TVD of Top and 24. TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MD 2-1/2" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 9846' 9788' MD TVD MD TVD 11230' - 11460' 8996' - 8998' 11550' - 11710' 8998' - 8993' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11940' - 12080' 8985' - 5978' DEPTH INTERVAL MD AMOUNT H~ KIND OF MATERIAL USED 12110' - 12220' 8977' - 8974' 12250' - 12500' 8973' - 8960' Freeze Protect w/ 152 Bbls Diesel 12640' - 12710' 8952' - 8948' 26. PRODUCTION TEST Date First Production: July 9, 2006 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date of Test 7/18/2006 Hours Tested 2.1 PRODUCTION FOR TEST PERIOD OIL^BBL gg GAS-MCF 807 WATER-BBL -0- CHOKE SIZE 83.14 GAS-OIL RATIO 8,200 Flow Tubing Press. 342 Casing Pressure 1,375 CALCULATED 24-HOUR RATE• OIL-BBL 1,124 GAS-MCF 9,220 WATER-BBL -0- OIL GRAVITV-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Sut~wit..cote.cl~ips; if none, state "none". c;..:v -~, ,~` ~ ~~ I ~ o~~; `~ 71'1 ~~~7 ~ ~'~ ~"~r.E3 None ~' G Vf IED Form 10 ~- rsed--'t12/2003 ONTINUED ON REVERSE SIDE S 4~! ~ JUL ~ ~ 2UU6 RIGIN~L !d®(- V ~ Q 28. GEOLOGIC MARKS 29. ORMATION TESTS Include and briefly summarize test results. List intervals tested, N/\ME MD TVD and attach detailed supporting data as necessary. If no tests were conducted state "None". Top HRZ 9152' 7638' None Base HRZ 9352' 7805' LCU 9357' 7809' Sag River 10015' 8352' Shublik A 10056' 8387' Shublik B 10089' 8416' Shublik C 10107' 8432' Sadlerochit 10143' 8465' Top CGL 10327' 8629' Base CGL 10410' 8701' 23TS 10475' 8757' 22TS 10506' 8783' 21 TS /Zone 2A 10606' 8859' Zone 1 B 10699' 8921' TDF /Zone 1A 10808' 8971' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the fore oing is true and correct to the best of my knowledge. ~7~ / /_ ~ ~ ~ / `F~ Title Technical Assistant Date Signed Terrie Hubble PBU 15-028 206-072 Prepared By NameMumber.~ Terrie Hubble, 564-4628 Drilling Engineer: Jeff Cutler, 564-4134 Well Number Permit No. / A royal No. INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 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. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval), IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List ail test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only T o m a ~, m r- ~ ~I v a a Cn ~ ~ M Q.. W ' I r ~ ' a x m n v n a 7'' N' y W ~ d M ~ a a ~ O ~ Y f6 N J N 7', y N .N y N d n ~. n n a ' r`ni °w m ~ ~ U N I ~ i N `-- f L ~ n a n z ~ n v n n ~ ~ ~ o ~ Q ~ ~ ' Q ~ I x w ,~ ~ o ~ ~ ~ ~ ~ ~ m ~' o 0 (~ d M M ~ r ~ J ' ~ ~ o ~~' ~ ' ~ ~' '~ o CV 0 O n d W O ~ ~ 00 O r ~ i H ~ d ~ N N ~ T' O O Y to ~ ~ T r ^ W ~_ ~_ z ~ °' CO o 0 ~ ~ Q N N N ' ~ ~ , .] BP EXPLORATION Page 1 of 16 Operations Summary Report Legal Well Name: 15-02 Common Well Name: 15-02 Spud Date: 2/12/1982 Event Name: REENTER+COMPLETE Start: 6/1/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 6/30/2006 Rig Name: NABOBS 27E Rig Number: 27E Date i -- - 6/1/2006 6/2/2006 6/3/2006 From - To ! Hours I Task I Code I NPT I Phase 00:00 - 06:00 6.00 MOB P 06:00 - 09:00 3.00 MOB P 09:00 - 12:00 12:00 - 15:00 15:00 - 18:00 18:00 - 20:00 20:00 - 00:00 00:00 - 01:00 01:00 - 04:00 3.00 MOB P 3.00 MOB P 3.00 MOB P 2.00 MOB P 4.00 MOB P 1.00 MOB P 3.00 MOB P 04:00 - 07:00 07:00 - 12:00 12:00 - 18:00 18:00 - 00:00 00:00 - 02:00 02:00 - 10:00 10:00 - 12:00 12:00 - 16:00 16:00 - 17:00 17:00 - 18:00 18:00 - 19:00 19:00 - 20:00 3.00 MOB P 5.00 MOB P 6.00 MOB P 6.00 MOB P 2.00 MOB P 8.00 MOB P 2.00 WHSUR P 4.00 WHSUR P 1.00 WHSUR P 1.00 WHSUR P 1.00 WHSUR P 1.001 W HSUR I P 20:00 - 22:00 2.00 WHSUR N 22:00 - 22:30 0.50 WHSUR P 22:30 - 00:00 1.50 WHSUR P Description of Operations -- PRE ~ Disconnect Complex's Interconnects. Remove All Berm Dunage, Check Tire Pressures, Function Tested Hydraulic Wheel Jacking Systems PRE Move Suppport Complexes from Around Rig and Stage for Transport to DS15. PRE Move Pump Room Complex, Pit Complex and Motor Complex to DS15 PRE Move Pipesheds to DS15 PRE Move Substructure Off of AGI-07A PRE Move Rear Substructure Wheel Cylinder to Inner Position, Clean Up Around Wellhead PRE Move Substructure with Derrick Up to DS15 PRE Move Substructure from East Side of Pad to West Side of Pad PRE Move Rear Substructure Well Cylinder Goose Necks to Outer Position. Lay Mats Aroung Well 02B and Cover with Herculite PRE Spot Substructure Over Well PRE Set Pipeshed Mats, Spot Pipsheds PRE Set Cuttings Tank, Pit Complex, Motor Complex and Pump Room Complex. PRE Hook Up Interconnect Lines PRE Spot Camp on Location, Set Camp Support Generator, Set Shop, Electrical Shop and Parts House PRE Berm Substructure, Pits Complex, Motor Complex and Camp Support Generator. Replaced Equalizer Valves Between Pits 3 &4and5&6. DECOMP PJSM; R/U Circulating Hoses to Circulating Manifold to Displace Weil with 140 deg. Water. DSM Unable to Pull BPV Because of Single Master Valve on Wellhead. ACCEPTED RIG FOR OPERATIONS AT 1000HRS, 6/3/06 DECOMP Ordered and Installed Swab Valve on Wellhead DECOMP Tested Tree, Circulating Manifold and Lines to 3,500 psi. DECOMP R/U DSM Lubricator, Pulled BPV, R/D Lubricator DECOMP Reversed Circulated 100 bbls 120 deg. Water at 5 bpm, 600psi Down 5-1/2" x 9-5/8" Annulus Taking Returns Up 5-1/2" Tubing to Slop Tank. DECOMP Shut Down Pumps and Switched Valves to Pump Down Tubing Taking Returns Off the Annulus to Slop Tank. Pumped 30 bbl Safe Surf O Pill at 5 bpm, 260 psi. Followed by 140 deg Water at 12 bpm, 700 psi. At 23 bbls Water Away Noticed Diesel Mist Coming Out Gas Buster Vent Line. Immediately Shut Down Pumps and Secured the Well. Discovered Diesel Mist Covered +/-60' x 60' Area. Notified 5700 and Reported Discharge to Bill Rodsky. HMAN DECOMP Started Spill Clean Up. Bagged Oily Absorbant in Double Oily Waste Bags. ACS Arrived on Location at 2030 hrs. Utilized Vac Truck on Location Suck Up Standing Snow Melt Water with Oily Sheen DECOMP Held PJSM with Rig Crew, Mudman, Toolpusher and WSL. Developed Procedure for Circulating Through the Choke Manifold/Gas Buster. DECOMP Displaced Diesel from 5-1/2" x 9-5/8" Annulus by Pumping Down the 5-1/2" Tubing. Pump Rates Below Rate Pressure BBLs Pumped Printed: 7/5/2006 10:10:38 AM ~' • BP EXPLORATION Page 2 of 16 Operations Summary Report Legal Well Name: 15-02 Common Well Name: 15-02 Spud Date: 2/12/1982 Event Name: REENTER+COMPLETE Start: 6/1/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 6/30/2006 Rig Name: NABOBS 27E Rig Number: 27E Date 6/3/2006 6/4!2006 6/5/2006 From - To ;Hours Task Code ~ NPT - - --' 22:30 - 00:00 ~ 1.50 WHSUR ~ P Phase DECOMP 00:00 - 02:30 I 2.501 WHSUR I P I I DECOMP 02:30 - 04:30 I 2.001 WHSUR I P I I DECOMP 04:30 - 06:00 1.50 WHSUR P DECOMP 06:00 - 07:00 1.00 WHSUR P DECOMP 07:00 - 08:30 1.50 BOPSU P DECOMP 08:30 - 17:00 8.50 BOPSU P DECOMP 17:00 - 18:00 1.00 BOPSU~ P DECOMP 18:00 - 22:00 4.00 BOPSU P DECOMP 22:00 - 23:00 I 1.001 BOPSUR P I I DECOMP 23:00 - 23:30 I 0.501 BOPSUR P I I DECOMP 23:30 - 00:00 0.50 BOPSU~N SFAL DECOMP 00:00 - 01:30 1.50 BOPSU N SFAL DECOMP 01:30 - 02:00 I 0.501 BOPSUR N I SFAL I DECOMP 02:00 - 03:00 1.00 BOPSU N SFAL DECOMP 03:00 - 03:30 0.50 BOPSU N SFAL DECOMP 03:30 - 04:30 1.00 BOPSU P DECOMP Description of Operations 1 bpm 0 psi 10 bbls 2 bpm 20 psi 20 bbls 3 bpm 50 psi 50 bbls 4 bpm 100 psi 100 bbls Diesel Out of Well Continued to Pump Down 5-1/2" Tubing Taking Returns Off 5-1/2" x 9-5/8" Annulus at the Following Rates Rate Pressure BBLs Pumped 4 bpm 100 psi 200 bbls 5 bpm 150 psi 400 bbls 6 bpm 230 psi 600 bbls 7 bpm 300 psi 1,000 bbls Clean Fluid at surface at 700 bbls Circulated 1 Bottoms Up After Clean Fluid to Surface M/U BPV and Running Tool on T-Bar. Set BPV, Would not Set, Removed BPV and Reset Locking Dogs, BPV Prematurely Set While on Rig Floor, Remove from Running Tool and Reset Again, Run BPV and Set. Tested from Below to 1,000 psi. Blow Down Circulating Lines and R/D Same PJSM; N/D Swab Valve, Master Valve and Adapter Valve Installed Blanking Plug in Tubing Hanger PJSM; N/U BOPE's. Move Stack from Cellar Pedistal to Wellhead. Installed BOPE Bolts and Torqued Same, Installed Double Annulus Valves, M/U Choke and Kill Lines, Set Drilling Riser. Installed 3-1/2" x 6" Variable Rams. M/U Flowline, Connected BOPE Securing Lines. Hook Up Auxiliary Lines and Drain Lines to Flowline. P/U 5-1/2" Test Joint. M/U XO, Pump in Sub, Floor Safety Valve. Installed Test Joint and Closed Lower Pipe Rams. M/U Test Manifold to Pump in Sub Test BOPE's. All Components Tested to 250 psi low / 3,500 psi high. All Tests Charted and Held 5 min Each. W ittness of Test Waived by AGOCC Rep. Chuck Scheeve. Tests Witnessed by WSL Rodney Klepzig and Nabors Tool Pusher Rick Brumley. Test Sequence 1. Lower Pipe Rams Blanking Plug Leaking by. Bled Down All Pressure R/D Test Manifold, Removed Test Joint and UD Same P/U 1 Jt. DP and M/U Blanking Plug Running Tool. Retrieved Bad Blanking Plug. Removed Bad Plug and Installed Good Plug on Running Tool. RIH and Set Plug. B/O and Remove DP Joint /Running Tool Closed Blind Rams and Tested Blanking Plug to 3,500 psi. Kill Line Connection Leaked. Bled Down All Pressure. Replaced Seal Ring in Kill Line Unibolt Connection Retest Blanking Plug, Blind Rams and Kill Line to 3,500 psi Test BOPE's. All Components Tested to 250 psi low / 3,500 psi high. All Tests Charted and Held 5 min Each. Wittness of Test Waived by AGOCC Rep. Chuck Scheeve. Tests Witnessed by WSL Rodney Klepzig and Nabors Tool Pusher Rick Brumley. Test Sequence 1. Blind Rams Printed: 7/5/2006 10:10:38 AM i r BP EXPLORATION Page 3 of 16 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date ;~ ~I Name: 1 ell Name: 1 e: Name: From - To j 5-02 5-02 REENTE NABOB NABOB i Hours ! R+COM S ALASK S 27E Task ! E PLET A DRI Code E LLING NPT Start I Rig Rig Phase Spud Date: 2/12/1982 : 6/1/2006 End: Release: 6/30/2006 Number: 27E Description of Operations 6/5/2006 03:30 - 04:30 1.00 BOPSU P DECOMP 2. Lower Pipe Rams, Floor Safety Valve 04:30 - 05:30 1.00 BOPSU N SFAL DECOMP Change Out Flow Line Air Boot in Substructure Corridor 05:30 - 10:00 4.50 BOPSU P DECOMP Continued to Test BOPE's Test Sequence 3. Upper Pipe Rams, Manual Kill and Choke Valves 4. Kill HCR, Choke Manifold Valves 1 & 2 5. Choke manifold Valves 3, 4, 5 & 6 6. Choke Manifold Valves 7, 8 & 9 7. Choke Manifold Valves 10, 11 & 12 8. Choke Manifold Valves 13, 14 & 15 9. Choke Manifold Valve 16 10. Annular, Lower Top Drive Well Control Valve 11. Upper Well Control Valve-Failed 10:00 - 11:00 1.00 BOPSU P DECOMP UD Test Joint, M/U Pump in Sub to Top Drive and Retest Upper Well Control Valve-Failed 11:00 - 15:00 4.00 BOPSU N SFAL DECOMP Removed Lower and Upper Well Control Valves 15:00 - 16:30 1.50 BOPSU P DECOMP M/U New Upper Well Control Valve and IBOP to Test Sub, Test Valves to 250 psi low / 3,500 psi high. Test Witnessed by WSL Chris Clemens. 16:30 - 17:00 0.50 BOPSU P DECOMP B/O Valves and R/D Testing Equipment 17:00 - 19:00 2.00 BOPSU P DECOMP P/U Joint DP and M/U Blanking Plug Retrieving Tool, Retrieve Blanking Plug, B/O Plug and Running Tool, VD DP 19:00 - 20:00 1.00 BOPSU P DECOMP PJSM, R/U DSM Lubricator Extension and Lubricator. Pull BPV. R/D Lubricator 20:00 - 22:00 2.00 BOPSU N SFAL DECOMP Installed New Upper Well Control Valve with Pneumatic Actuator, M/U Lower Well Control Valve 22:00 - 23:00 1.00 PULL P DECOMP P/U and M/U Double Spear Assy. with 4.805 Grapples to 1Joint DP. RIH and Spear Tubing Hanger 23:00 - 23:30 0.50 PULL P DECOMP BOLDS, Pull Tubing Hanger to Rig Floor with 180K Up Weight 23:30 - 00:00 0.50 PULL P DECOMP Circulated Surface to Surface at 9 bpm , 700 psi 6/6/2006 00:00 - 00:30 0.50 PULL P DECOMP Circulated at 9 bpm, 700psi 00:30 - 01:00 0.50 PULL P DECOMP B/O and UD Spear Assy. UD Joint DP 01:00 - 01:30 0.50 PULL P DECOMP B/O and UD Tubing Hnager 01:30 - 03:30 2.00 PULL P DECOMP POH laying down 5-1/2" 17# L-80 LTC-ABM Tubing 03:30 - 08:30 5.00 PULL N RREP DECOMP Replaced Pipe Skate Hydraulic Pipe Ejector Cylinder 08:30 - 10:30 2.00 PULL P DECOMP POH laying down 5-1/2" 17# L-80 LTC-ABM Tubing 10:30 - 11:00 0.50 PULL N RREP DECOMP Replace bad hose on link tilt 11:00 - 11:30 0.50 PULL P DECOMP POH laying down 5-1/2" 17# L-80 LTC-ABM Tubing 11:30 - 12:00 0.50 PULL P DECOMP Rig down control line spooler. Recovered 26 clamps and 26 pins and 4 stainless bands. 12:00 - 20:30 8.50 PULL P DECOMP POH laying down 5-1/2" 17# L-80 LTC-ABM Tubing. A total of 229 jts, an 11.67' stub, and a SSSV assy were pulled and layed down. 20:30 - 21:30 1.00 PULL P DECOMP Rig down casing equipment 21:30 - 22:30 1.00 BOPSU P DECOMP Make up test jt to test bope 22:30 - 00:00 1.50 BOPSU P DECOMP Test top/lower variable pipe rams and hydril around 4" dp. Tested 250 psi low - 3500 psi high for five minutes each and recorded on chart. AOGCC Chuck Scheeve waived to witness test. Witnessed by WSL Charlie Noakes and TP Rick Brumley. Install wear ring, RILDS 6/7/2006 00:00 - 00:30 0.50 BOPSU P DECOMP Lay down wear ring puller and test jt. 00:30 - 10:00 9.50 CLEAN P DECOMP Make up milling assembly, RIH picking up 4" dp 1x1. 10:00 - 15:00 5.00 CLEAN N RREP DECOMP Replace pipe skate injector. Printed: 7/5/2006 10:10:38 AM • BP EXPLORATION Page 4 of 16 Operations Summary Report Legal Well Name: 15-02 Common Well Name: 15-02 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 27E Date From - To ~ Hours Task ~ Code NPT 6/7/2006 15:00 - 16:00 1.00 EVAL P 16:00 - 17:00 1.00 CLEAN P 17:00 - 20:00 3.00 CLEAN N RREP 20:00 - 21:30 I 1.50 I CLEAN I P 21:30 - 23:00 I 1.50 I CLEAN I P 23:00 - 00:00 1.00 CLEAN P 6/8/2006 00:00 - 01:00 1.00 CLEAN P 01:00 - 01:30 0.50 CLEAN N 01:30 - 03:30 2.00 CLEAN P 03:30 - 05:00 1.50 CLEAN P 05:00 - 05:30 0.50 CLEAN P 05:30 - 08:30 I 3.00 I CLEAN I P 08:30 - 11:30 3.00 DHB P 11:30 - 12:30 1.00 CASE P 13:00 - 16:30 3.50 BOPSUR P 16:30 - 17:30 1.00 WHSUR P 17:30 - 19:00 1.50 WHSUR P 19:00 - 22:00 3.00 BOPSUF{ P 22:00 - 23:30 1.50 BOPSU P 23:30 - 00:00 0.50 STWHIP P 6/9/2006 00:00 - 04:00 4.00 STW H I P P 04:00 - 05:00 I 1.001 STWHIPI P 05:00 - 06:00 I 1.001 STWHIPI P 06:00 - 07:00 1.00 STWHIP P 07:00 - 13:30 6.50 STWHIP P RREP Spud Date: 2/12/1982 Start: 6/1/2006 End: I Rig Release: 6/30/2006 Rig Number: 27E Phase i Description of Operations DECOMP Safety stand down on enviromental and safety. DECOMP RIH with milling assembly picking up 4" dp 1x1. DECOMP Clean up glycol spill from brake cooling system overflow. Approximately 40 gallons spilled in containment. DECOMP RIH with milling assembly picking up 4" dp 1x1. Tagged 5-1/2" stump at 8765', which is ten feet deeper than wireline measurement. DECOMP Circulate bottoms up at 600 gpm at 2250 psi. At 4000 stks gas was breaking out at surface. The pump was shut down and we o~erved the well. Gas was breaking out but no flow. Shut the w II in and circulated 1100 stks at 5 bpm at 375 psi through the choke. No gas observed or smelled coming out of the gas buster. Once we had bottoms up we turned the pump off and shut the well in. SIDPP =0, SICP=O. Opened up the choke line and opened up the hydril. No flow. Circulated another 500 stks, gas quit bubbling, shut the pump off and observed the well for 5 minutes, no flow. Possible gas migrated from between tubing cut off at 8965' and TOC at 9700'. DECOMP Pump dry job and POH. Water wt=8.4 ppg in/out. DECOMP POH with milling assy. DECOMP Work on Draw Works DECOMP POH with milling assy to bha. DECOMP Stand back 20 hwt, jar and 9 dc's. DECOMP lay down XO, float sub, 1 jt hwt, watermellon mill, bit sub, and starting mill. DECOMP Rig up Schlumberger, run 8-1/2" gauge ring, junk basket and GR/CCL, tagged up on tubing stump at 8965', no significant debris. DECOMP Run #2, Set EZSV at 8815', 5' above a casing collar, POH, rig down Schlumberger. DECOMP Test 9-5/8" casing against EZSV at 3500 psi for 30 minutes. OK, Monitor well. DECOMP Drain stack, pull wear bushing. DECOMP Nipple down flow line, riser, BOP, pull off tubing spool and 9-5/8" pack off. DECOMP Set new 9-5/8" pack off, nipple up Gen II retro tubing spool. DECOMP FMC prep spool, test 9-5/8" packoff and bottom flange of tubing spool to 5000 psi for 10 minutes. DECOMP Nipple up BOP, riser, and flow line. DECOMP Test top flange of Gen II retro spool, HCR choke/kill line valves, and Hydril annular preventer to 250 psi low / 3500 psi high for 5 minutes each. Test witnessed by WSL Charlie Noakes and TP Rick Brumley. Lay down test jt. WEXIT Pick up whipstock and milling assy. WEXIT Pick up whipstock, starter mill, bit sub watermellon mill, 1 HWT, float sub, XO, MWD, UBHO sub, orient MWD and UBHO sub to whipstock, program MWD. WEXIT RIH with 9 dc's, shallow pulse test MWD, pick up XO, bumper sub, 21 hwt, XO. WEXIT RIH as per RP and Baker fishing hands recommendation with whipstock and milling assy. 90 to 120 seconds per stand. WEXIT Serice top drive, install blower hose, fill pipe. WEXIT RIH as per RP and Baker fishing hands recommendation with Printed: 7/5/2006 10:10:38 AM BP EXPLORATION. Page 5 of 16 ..Operations Summary Report Legal Well Name: 15-02 Common Well Name: 15-02 Spud Date: 2/12/1982 Event Name: REENTER+COMPLETE Start: 6/112006. End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 6!30/2006 Rig Name: NABOBS 27E Rig Number: 27E Date I From - To Hours Task Code NPT Phase Description of Operations 6/9/2006 107:00 - 13:30 6.50 STWHIP P WEXIT whipstock and milling assy. 90 to 120 seconds per stand. Fill 13:30 - 14:00 1 0.501 STWHIPI P 14:00 - 16:00 2.00 STWHIP P 16:00 - 00:00 8.00 STWHIP P 16/10/2006 100:00 - 02:00 02:00 - 04:30 04:30 - 06:00 2.00 STWHIP P 2.50 STWHIP P 1.50 STWHIP P 06:00 - 06:30 0.50 STWHIP P 06:30 - 12:00 5.50 STWHIP P 12:00 - 13:30 1.50 STWHIP P 13:30 - 14:00 0.50 STWHIP P 14:00 - 14:30 0.50 STWHIP P 14:30 - 15:00 0.50 STWHIP P 15:00 - 16:30 1.50 STWHIP P 16:30 - 18:30 16/11/2006 18:30 - 19:00 19:00 - 19:30 19:30 - 22:00 22:00 - 22:30 22:30 - 23:30 23:30 - 00:00 00:00 - 02:30 02:30 - 05:30 2.001 STWHIPIP 0.50 STWHIP P 0.50 STWHIP P 2.50 STWHIP P 0.50 STWHIP P 1.00 STWHIP P 0.50 STWHIP P 2.50 STWHIP P 3.00 STWHIP P 05:30 - 05:45 0.25 DRILL P 05:45 - 06:30 0.75 DRILL P 06:30 - 07:00 0.50 DRILL P 07:00 - 00:00 17.00 DRILL P 6/12/2006 100:00 - 05:30 1 5.501 DRILL I P pipe every 30 stands. Make Madd Pass from 8554' to 8750' at 100'/hr. WEXIT Orient whipstock 76L of HS at 8694', set at 8815' ab76L"of HS. UW_195k, DW=165k, 500 gpm at 2080 psi. TbW=8TS4 ': ;BOW=8810'..' , WEXIT Pump 50 bbl duo visc spacer (3 Ibs/bbl), displace well with 10.1 ppg LSND mud at 500 gpm, 2000 psi.. WEXIT Mill window F/8794' - T/8804'. 500 gpm, 2550 psi, UW=200k, ~ DW=165k, RW=1178k, off bot tq=4k-5k, on bot tq=4k-8k, 90 rpms rot, 10.1 ppg in/out, yp=40. WEXIT Miil window F/8804' - T/8810'. 500 gpm, 2550 psi, UW=200k, DW=165k, RW=1178k, off bot tq=4k-5k, on bot tq=4k-8k, 90 rpms rot, 10.1 ppg in/out, yp=40. WEXIT Drill F/8810' - T/8820'. Mill not making any progress. 30k wt on bit, 500 gpm, 2600 psi, UW=200k, DW=165k, RW=1178k, off bot tq=4k-5k, on bot tq=4k-Sk, 90 rpms rot, 10.1 ppg in/out, yp=40. WEXIT Pump 23 bbl Super Sweep, 600 gpm at 3400 ppsi, 110 rpm's, 165k rot, 40 yp, 10.1 ppg inlout. 20% increase in cuttings returns. WEXIT Mix and pump dry job. ~ WEXIT POH, stand hwdp back in derrick. ~, W EXIT Lay down steel dc's. .WEXIT DownloadMWDtools. WEXIT lay down MWD, bumper sub, and milling assy. WEXIT Lay down bha off rig floor. WEXIT Pick up stack washing assy, flush stack, pull wear ring, flush stack, function rams to clear debris, repeat stack flush, service and reinstall wear ring. WEXIT Pick up bit, mud motor, flt sub, stab, mwd, 3 nmfdc's, 6 hwdp, drlg jar, 15 hwt, and xo. WEXIT RIH picking up 4" dp 1 x 1. (9 jts.) WEXIT Shallow pulse test MWD. WEXIT RIH picking up 4" dp 1 x 1. (64 jts.) WEXIT Change out dies on Iron Roughneck, inspect pipe skate. WEXIT RIH picking up 20 jts 4" dp 1 x 1 for a total of 93 jts. WEXIT Cut and slip drilling line. WEXIT Cut and slip drilling line, service top drive and blocks. WEXIT TIH to 8,735', set depth, fill pipe, orient motor to 80 left of highside, shut off mud pumps, exit window, no problem going through window. UW=185k, DW=155k. INT1 Slide from 8,820' to 8,822', pick up 5' to 8,817' to circulate bottoms up for FIT. 500 gpm at 2,550 psi. INTi Circulate bottoms up at 500 gpm, 2,550 psi. INT1 Pull up into 9-5/8" casing to 8,766', mw=10.1 ppg in/out, perform FIT to 11.5 ppg. (535 psi.) INT1 Directional drill 8-1/2" hole F/8,822' - T/9,700' as per Sperry Sun dd's. Dritf Kingak as per RP. Maintain 100'/hr rop, 500 gpm at 3,040 psi, UW=f85k, DW=155k, RW=170k, 80 rpm's, tq on=5,500, tq off=4,500, MW=102 ppg in/out. Pumped high visc sweep at 9,500'. Yp 85, 25% increase in cuttings returns. INT1 Directional drill 8-1/2" hole F/9,700' - T/10,0000' as per Sperry Printed: 7/5/2006 10:10:38 AM r1 ~~ BP EXPLORATION Page 6 of 16 Operations Summary Report Legal Well Name: 15-02 Common Well Name: 15-02 Spud Date: 2/12/1982 Event Name: REENTER+COMPLETE Start: 6/1/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 6/30/2006 Rig Name: NABOBS 27E Rig Number: 27E Date ~ From - To Hours I Task ~ Code i NPT I Phase Description of Operations ~ ~ -- -_ - -- 6/12/2006 ~ 00:00 - 05:30 5.50 DRILL ~ P I INT1 05:30 - 06:30 1.00 DRILL P INT1 06:30 - 07:30 1.00 DRILL P INT1 07:30 - 09:00 ~ 1.50 ~ DRILL ~ P ~ ~ INTi 09:00 - 10:30 I 1.501 DRILL I P I I INT1 10:30 - 11:30 1.00 DRILL P INT1 11:30 - 13:00 1.50 DRILL P INT1 13:00 - 15:00 I 2.001 DRILL I P I I INT1 15:00 - 15:30 0.50 DRILL P INT1 15:30 - 19:30 4.00 DRILL P INT1 19:30 - 21:30 2.00 DRILL P INT1 21:30 - 22:30 1.00 DRILL P INT1 22:30 - 23:30 1.00 DRILL P INT1 23:30 - 00:00 0.50 DRILL P INT1 6/13/2006 00:00 - 00:30 0.50 DRILL P LNR1 00:30 - 01:30 1.00 CASE P LNR1 01:30 - 02:00 0.50 CASE P LNR1 02:00 - 06:00 4.00 CASE P LNR1 06:00 - 06:30 I 0.501 CASE I P I I LNR1 06:30 - 12:00 I 5.501 CASE P LNR1 12:00 - 14:00 I 2.001 CASE I P I I LNR1 14:00 - 15:00 ~ 1.001 CASE ~ P ~ I LNR1 15:00 - 17:00 I 2.001 CASE I P I f LNRt 17:00 - 18:30 l 1.501 CASE I P LNR1 Sun dd's. Drill Kingak as per RP. Maintain 100'/hr rop, 500 gpm at 3,040 psi, UW=185k, DW=155k, RW=170k, 80 rpm's, tq on=5,500, tq off=4,500, MW=10.2 ppg in/out. Circulate sample up to help geology pick casing point, TSAG. Directional drill 8-1/2" hole F/10,000' - T/10,010' as per Sperry Sun dd's. Drill Kingak as per RP. Maintain 100'/hr rop, 500 gpm at 3,040 psi, UW=185k, DW=155k, RW=170k, 80 rpm's, tq on=5,500, tq off=4,500, MW=10.2 ppg in/out. AST=.64, ART=3.76, ADT=4.4. Pump 24 bbl hi vise sweep, YP=118, 300 vise, 10.2 ppg, work pipe at 80 rpm's, 500 gpm at 2,980 psi, circulate bottoms up, 10 % increase in cuttings returns. MW=10.2 ppg in/out. Short trip through the window to 8,735', Stab tight going through window, work pipe through, OK. Service top drive, draw works, and crown. Clean rig floor. Orient to window, took 10k to push string stab through window, TIH, no problems. Pump high vise sweep, wt 10.2 ppg, vise 300, yp=118, 475 gpm, 2,635 psi, 100 rpm's, uw=190k, do=150k. MW=10.2 ppg in/out. Monitor well, pump dry job. POH to HWDP. Lay down HWDP and NMDC's. Download MW D. Lay down MW D, stab, flt sub, mud motor, bit. Clear rig floor, clean out drip pan. Clean out drip pan. Rig up to run 7" drilling liner. Hold PJSM with rig crew and service hands. Make up shoe track, Bakerloc first two joints to the Insert Landing Colfar. Run third jt, fill pipe, pick up 40', come back down, check floats, OK. Run flt shoe, 7" csg jt, flt collar, 7" csg jt, Baker insert landing collar in bottom of third jt, run 30 jts 7" csg jts for a total of 32 jts plus the float equipment. Pick up liner top packer and liner hanger, inspect, make up in string. Run 1 stand 4" dp in hole, lay down top jt to space out landing depth. Circulate volume of 7" drilling liner. 52 bbls at 4 bpm, 150 psi. Liner wt=32k. TIH with liner on 4" dp to top of window at 8,700'. Fill pipe and record up and down weights every 10 stands. At window up wt=150k, dw=135k. Circulate 1.5 times bottoms up. Stage up at 2 bpm for 5 minutes, increasing by 1 bpm every 5 minutes achieving 6 bpm at 705 psi with no losses. UW=160k, DW=135k. TIH with liner on 4" dp to 10,010', no problem going through the window. Make up cement head and cement lines with Tee to test and wash up through. Establish circulation at 2 bpm, 500 psi. Stage up to 6 bpm at 1,100 psi for final circulating rate. No losses, MW=10.2 ppg in/out. Hold PJSM with all personel while circulating. Pump 5 bbls water, test surface lines to 4,000 psi. Bleed off down flowline, pump through tee until mudpush seen. Dowell pumped 30 bbls 11.5 ppg mudpush XL followed by 57 bbls Printed: 7/5/2006 10:10:38 AM • • BP EXPLORATION Page 7 of 16 Operations Summary Report Legal Well Name: 15-02 Common Well Name: 15-02 Spud Date: 2/12/1982 Event Name: REENTER+COMPLETE Start: 6/1/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/30/2006 Rig Name: NABORS 27E Rig Number: 27E Date ~ From - To Hours I Task Code ! NPT ~ Phase ~, Description of Operations 6/13/2006 17:00 - 18:30 1.50 CASE P LNR1 15.8 ppg class G cement. Drop wiper dart and chase with 5 bbis water to clear cement lines. Displaced cement with rig pumps at 6 bpm. Latched wiper dart into hanger plug 87 bbis away, continued displacement, bumped plug at calculated strokes, pressured up to 3,500 psi. Slack off string wt to 120k, bleed off pressure and check floats, floats held. Rotate string 15 turns to the right, pressure up to 1,000 psi, P/U 10' to clear setting dogs. Observed pressure loss, pump at 8 bpm, 1,575 psi for 40 bbis, slowed pump to 1 bppm and p/u to 155k. Rotated at 20 rpm's and slacked off to 80k to confirm packer set. 18:30 - 19:30 1.00 CASE P LNR1 Circulate out contaminated mud to surface at 8.5 bpm at 1,700 psi. No straight cement back. 25-30 bbis contaminated cement back. 19:30 - 20:30 1.00 CASE P LNR1 POH 25 stands, lay down cement head, hoses, and manifold. 20:30 - 00:00 3.50 CASE P LNR1 POH with 4" dp and 7" liner packer running tool. 6/14/2006 00:00 - 01:00 1.00 CASE P LNR1 POH with 4" dp and liner packer running tool, lay down running tool. 01:00 - 02:00 1.00 CASE P LNR1 Service top drive, draw works, and crown. 02;00 - 05:00 3.00 DRILL P PROD1 Hold PJSM, pick up insert bit, ABI motor, NM flt sub, stab, MWD, 1 nmfdc. 05:00 - 06:00 1.00 DRILL P PROD1 Initialize MWD. 06:00 - 07:00 1.00 DRILL P PROD1 Pick up 2 nmfdc's, drilling jar, Baker circ. sub, and xo. 07:00 - 07:30 0.50 DRILL P PROD1 PJSM on picking up 4" dp up out of the pipe shed. 07:30 - 09:00 1.50 DRILL P PROD1 TIH picking up 51 jts dp 1 x 1 out of the shed. 09:00 - 12:00 3.00 DRILL P PROD1 TIH to 9,702' with 6-1/8" build assy. 12:00 - 15:30 3.50 DRILL P PROD1 Circulate and condition mud prior to testing 7" liner. UW=170k, DW=135k. 15:30 - 16:30 1.00 DRILL P PROD1 Test 7" casing to 3,500 psi for 30 minutes at 9,702'. Pumped 7.5 bbis to achiecve 3,500 psi, bled off, 7.5 bbls returned. MW=10,2 ppg in/out. 16:30 - 19:30 3.00 DRILL P PROD1 Drill intermittent stringers of cement F/9,748' - T/9,921'. UW=175k, DW=145k, RW=154k, 30 rpm's, 248 gpm at 1,890 psi, tq on=5,500, tq off=4,500. 19:30 - 21:30 2.00 DRILL P PROD1 Drill landing collar. 6k-16k wt on bit, 30 rpm's, 250 gpm at 2,000 psi. 21:30 - 22:30 1.00 DRILL P PROD1 Drill cement and float collar F/9,921' - T/10,009', stopping on top of float shoe. 22:30 - 00:00 1.50 DRILL P PROD1 Flush both mud pumps and suction lines with 8.4 ppg Flo Pro. Displace hole with 100 bbis water spacer, 30 bbls high visc spacer, followed by 8.4 ppg Flo Pro, YP=26 6/15/2006 00:00 - 03:00 3.00 DRILL P PROD1 Displace well with 8.4 ppg Flo Pro, YP=26. Once clean FLO Pro came back we shut down and cleaned possum bellies and trough, flushed mud pit centrifigul lines with Flo Pro before starting to drill. 250 gpm at 1,500 psi. 03:00 - 03:30 0.50 DRILL P PROD1 Drill float shoe and 20' new hole. Slide from 10,010' to 10,030'. 250 gpm at 1,500 psi. 03:30 - 04:00 0.50 DRILL P PROD1 Circulate until mud wt evened out. 8.5 ppg in/out. 04:00 - 04:30 0.50 DRILL P PROD1 Conduct FIT to 10.3 ppg, 780 psi. Pumped 1.7 bbis to achieve 10.3 ppg FIT. 04:30 - 05:00 0.50 DRILL P PROD1 Bleed pressure off, line mud system back up to drill ,gained back 1.7 bbis. 05:00 - 00:00 19.00 DRILL P PROD1 Directional drill 6-1/8" production hole from 10,030' to 10,550' Printed: 7/5/2006 10:10:38 AM • • BP EXPLORATION Page 8 of 16 Operations Summary Report Legal Well Name: 15-02 Common Well Name: 15-02 Spud Date: 2/12/1982 Event Name: REENTER+COMPLETE Start: 6/1/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 6/30/2006 Rig Name: NABOBS 27E Rig Number: 27E Date I From - To ~ Hours ~ Task Code ~ NPT Phase Description of Operations i_ _ i - - -- _ __ 6/15/2006 ~ 05:00 - 00:00 ~ 19.001 DRILL P ~ ~ PROD1 ~as per SSDS dd's. 250 gpm, 1,520 psi off bot, 1,640 psi on 6/16/2006 100:00 - 21:00 21.00 DRILL I P PROD1 21;00 - 22:00 I 1.001 DRILL P PROD1 22:00 - 23:00 I 1.001 DRILL I P I I PROD1 23:00 - 00:00 1.001 DRILL P I PROD1 6/17/2006 100:00 - 04:30 4.501 DRILL P I PROD1 04:30 - 05:00 0.50 DRILL P PROD1 05:00 - 07:00 2.00 DRILL P PRODi 07:00 - 08:00 1.00 DRILL P PROD1 08:00 - 09:30 1.50 DRILL P PRODi 09:30 - 14:00 4.50 DRILL P PROD1 14:00 - 15:00 1.00 DRILL P PROD1 15:00 - 16:00 1.00 DRILL P PROD1 16:00 - 17:00 1.00 BOPSU P PROD1 17:00 - 17:30 0.50 BOPSU P PROD1 17:30 - 18:30 1.00 BOPSU P PROD1 18:30 - 22:30 4.00 BOPSU N SFAL PRODi 22:30 - 00:00 I 1.501 BOPSUFi P I I PROD1 6/18/2006 00:00 - 03:30 3.501 BOPSUp P PROD1 03:30 - 06:00 2.501 BOPSUp N SFAL PROD1 06:00 - 07:00 I 1.001 DRILL I P I I PROD1 bot, 50 rpm's, UW=184k, DW=156k, RW=168k, tq on=4.5k, tq off=3.5k. MW=8.5 ppg iNout. Directional drill 6-1/8" production hole from 10,550' to 11,036' as per SSDS dd's. 250 gpm, 1,689 psi off bot, 1,740 psi on bot, 50 rpm's, 15k wob, UW=190k, DW=156k, RW=170k, tq on=5k, tq off=3.5k. AST=7.94, ART=4.52, ADT=12.46. Circulate sample up for geologist, pump hi visc sweep (50 YP) into 9-5/8" casing. 50 rpm's, 250 gpm, 1,600 psi, MW=8.5 ppg in/out. Monitor well, pull out of open hole to inside 7" liner at 10,010'. No overpull, hole looked to be in good shape. Drop ball to open Baker circ sub, pump high visc sweep out of hole at 600 gpm at 1,500 psi. 10% increase in cuttings with sweep. Monitor well 10 minutes, POH to pick up 5" ABI motor, adjust motor to 1.5 degree bend, p/u pdc bit. Monitor well 10 minutes, Lay down XO, Baker circ sub. Flush mud motor with fresh water, stand back nmfdc's, break off bit. Download MWD, monitor well. Pull MW D probe, lay down gamma /res, dm collar, stab, float sub, and motor. M/U 6-1/8" Hughes pdc bit, 5" ABI mud motor set at 1.5 degrees, orient MWD to motor, make up float sub, stab, DM collar, gamma /res, nukes. Rebuild TM collar, make up same, initialize MWD tools. Hold PJSM, load sources in neutron tool, RIH with 1 stand 4.75" nmfdc's, jar, Baker circ sub, and XO. TIH with 10 stands 4" dp, RTTS, 1 stand 4"dp, set RTTS, POH with running tool, lay down same. Test RTTS to 1,000 psi. UW=69k, DW=69k Rig up wear ring puller, pull wear ring, install test plug. Hold PJSM to test BPOE. Make up test joint. Test plug wouldn't seal, pull test plug, change rubber, try to test, still leaking around seals. Run 4 LDS in to energize seal rubber without any success. Pull test plug, flush stack with ported sub, 25 spm, 30 rpm's, 55 psi. Call FMC for new test plug, run new test plug in hole. New test plug sealed ok. Test BOPE 250 psi low, 3,500 psi high, hold for 5 minutes each. Test witnessed by AOGCC Jeff Jones, BP wellsite leader Charlie Noakes, and Nabors tour pusher Dave Richards. Test BOPE 250 psi low, 3,500 psi high, hold for 5 minutes each. Set wear ring and lay down test joint. Test witnessed by AOGCC Jeff Jones, BP wellsite leader Charlie Noakes, and Nabors tour pusher Dave Richards. Gas monitor for LEL and H2s not working, work to get system up and running properly. Tested Gas Monitoring Systems and witnessed by WSL Rodney Klepzig Service Top Drive, Drawworks, Iron Roughneck, Crown and Blocks Printed: 7/5/2006 10:10:38 AM BP EXPLORATION Operations Summary Report s Page 9 of 16 Legal Well Name: 15-02 Common Well Name: 15-02 Spud Date: 2/12/1982 Event Name: REENTER+COMPLETE Start: 6/1/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 6/30/2006 Rig Name: NABOBS 27E Rig Number: 27E Date !, From - To Hours ' Task Code NPT Phase -- --- _ __ 6/18/2006 ~ 07:00 - 09:00 ~ 2.00 DRILL ~ P PROD1 09:00 - 09:30 0.50 DRILL P PROD1 09:30 - 15:00 5.50 DRILL P PROD1 15:00 - 20:00 ~ 5.00 ~ EVAL i P ~ ~ PROD1 20:00 - 21:00 I 1.001 DRILL I P I I PROD1 21:00 - 23:30 ~ 2.50 ~ DRILL ~ N ~ DPRB ~ PROD1 23:30 - 00:00 0.50 DRILL N DPRB PROD1 6/19/2006 00:00 - 00:30 0.50 DRILL N DPRB PROD1 00:30 - 06:00 5.50 DRILL N DPRB PROD1 06:00 - 06:30 0.50 DRILL N DPRB PROD1 06:30 - 08:00 1.50 DRILL N DPRB PROD1 08:00 - 10:00 2.00 DRILL N DPRB PROD1 10:00 - 11:00 1.00 EVAL N DPRB PROD1 11:00 - 12:00 1.00 DRILL N DPRB PROD1 12:00 - 13:00 1.00 STKOH N DPRB PROD1 13:00 - 14:00 1.00 STKOH N DPRB PROD1 14:00 - 15:00 1.00 STKOH N DPRB PROD1 15:00 - 20:00 5.00 STKOH N DPRB PRODi 20:00 - 20:30 0.50 STKOH N DPRB PRODi Description of Operations P/U 1 stand 4" DP and retrieve Halliburton RTTS. RTTS running tool failed to M/U fully with tool. Released tool from RTTS and flushed thread profile w/ mud at 4 bpm. Re-engaged RTTS and POH w/ same. L/D running tool and RTTS Flow Test MWD at 70spm/300gpm, 1,050 psi RIH w/ 6-1/8" Hughes PDC, 5" Motor with 1.5 deg. Bend. f/ 1,175' - U10,610'. MAD Pass f/10,610' - t/11,036'. 300 gpm, 1,950 psi, 110'/hr, 40 rpm's. Directional drill 6 1/8" production hole as per SSDS dd's f/11,036' - t/11,083'. Survey shows 48 degrees inc and 327 degrees az. Realize hole is sidetracked at start of Mad Pass. POH to 10,550', take checkshot to confirm inclinometer isn't stuck in the MWD tool, survey is 36 degrees, which matches up with previous tool run. Rig team decided to open hole sidetrack with this assy at 10,550', then POH to bend motor to 1.83 and pick up a Hughes MX18 rollercone to drill the curve. MW=8.5ppg in/out. Trough hole f/10,562' - t/10,568'. Trough 6-1/8" hole F/10,568' - 7/10,574'. UW=190k, DW=160k, RW=170k, TO off=3,500, TO on=4,500, 300 gpm, Off bot=1,880 psi, On bot=2,120 psi. MW=8.5 ppg/in/out. POH to 7" shoe, monitor well, pump dry job, POH to bha. Lay down xo, circ sub, jar. Hold PJSM, stand back nmfdc's, remove sources from neutron tool. Plug into MWD tool and download information. Wait on orders while reviewing directional plan. L/D TM collar, neutron tool, break off bit. Make up Hughes MX 18HDX, bend motor to 1.76 degrees, drop stab off top of mud motor to enhance build. Plug in and initialize MWD tool. Make up 3 nmfdc's, jar, circ sub, xo, and 1 stand dp. Shallow pulse test MWD. TIH to shoe, fill pipe. TIH to 10,485', line up motor to a HS TF, RIH to 10,610'. 20:30 - 21:30 1.00 STKOH N DPRB PROD1 21:30 - 22:30 1.00 STKOH N DPRB PROD1 22:30 - 23:00 0.50 STKOH N DPRB PROD1 23:00 - 00:00 1.00 ~ STKOH N DPRB PROD1 6/20/2006 ~ 00:00 - 01:00 1.00 STKOH i N DPRB PROD1 01:00 - 01:30 I 0.501 STKOH I N I DPRB I PROD1 Orient TF to 180 to ensure getting into Mad Pass sidetrack to retrieve surreys ,TIH to 11,000'. The hole was trying to pack off, pulled up to 10,958' with no problems. POH from 10,958' to 10, 632' taking surveys every 45' to 50'. Average inclination was 50 to 52 degrees. POH to 10,530', orient TF to 180, slide down to sidetrack depth of 10,562'. Directional drill 6-1/8" production hole as per SSDS dd's. Slide F/10,562' -7/10,592'. 250 gpm, pp off=1,536 psi, pp on=1,640 psi, wob=l3k, uw=190k, dw=155k, rw=170k, tq off=3.5k, tq on=4.5k. AST=.4, ART=O, ADT=.4. Directional drill 6-1/8" production hole as per SSDS dd's. Slide F/10,592' - 7/10,644'. 250 gpm, pp off=1,536 psi, pp on=1,640 psi, wob=l3k, uw=190k, dw=155k, rw=170k. Pull up to 10,538', rotate from 10,538' to 10,644', getting back into the new sidetrack with no problems. Printed: 7/5/2006 10:10:38 AM • BP EXPLORATION Operations Summary Report Legal Well Name: 15-02 Common Well Name: 15-02 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 27E Date ~ From - To 1 Hours ~ Task Code ~ NPT _- ~ _ ,- - 1 Start: 6/1 /2006 Rig Release: 6/30/2006 Rig Number: 27E Phase 6/20/2006 101:30 - 12:00 ~ 10.50 ~ STKOH ~ N DPRB ~ PROD1 12:00 - 14:00 I 2.00 STKOH N I DPRB PROD1 14:00 - 14:30 0.50 STKOH N DPRB PROD1 14:30 - 15:00 0.50 STKOH N DPRB PROD1 15:00 - 16:30 I 1.501 STKOH I N I DPRB I PROD1 16:30 - 20:30 4.00 STKOH N DPRB PROD1 20:30 - 21:00 0.50 STKOH N DPRB PROD1 21:00 - 21:30 0.50 STKOH N DPRB PRODi 21:30 - 00:00 2.50 STKOH N DPRB PROD1 6/21/2006 00:00 - 01:00 1.00 STKOH N DPRB PROD1 01:00 - 02:00 1.00 STKOH N DPRB PROD1 02:00 - 03:00 I 1.00 STKOH N I DPRB PROD1 03:00 - 04:00 1.00 STKOH N DPRB PROD1 04:00 - 04:30 0.50 STKOH N DPRB PROD1 04:30 - 06:30 2.00 STKOH P PROD1 06:30 - 10:00 3.50 STKOH N DPRB PROD1 10:00 - 10:30 0.50 STKOH N DPRB PROD1 10:30 - 11:00 I 0.501 STKOH N I DPRB PROD1 11:00 - 12:00 I 1.001 DRILL I P I I PROD1 12:00 - 00:00 12.001 DRILL (P I PROD1 6/22/2006 100:00 - 12:00 I 12.001 DRILL I P I I PRODi Page 10 of 16 Spud Date: 2/12/1982 End: Description of Operations Directional drill 6-1/8" production hole as per SSDS dd's. Slide F/10,644' - T/11,020', rotate F/11,020' - T/ 11,053'. 250 gpm, pp off=1,536 psi, pp on=1,800 psi, wob=20k, uw=190k, dw=160k, rw=170k, tq off=4k, tq on=5k. Circulate sample up for geology. 250 gpm, 1,540 psi, 50 rpm, rw=170k, mw=8.6 ppg in/out. Backream F/11,053' - T/10,550' in order to clean up build section. Rw up=180k, tq=4k, 60 rpm's, 2,285 psi, 340 gpm. TIH T/10,674', survey to confirm we were able to get back in the right hole, POH to shoe. Drop bar opening circ sub, pump high visc sweep at 14 bpm, 2,700 psi, 60 rpm's. Loaded shakers up with cuttings. Monitor well 10- min, pump dry job. POH to bha. Lay down xo, circ sub, jar, stand back 3 nmfdc's. Down load MWD. Service rig at same time. Change bit, bend motor to 1.5 degrees, change pulser, make up nuke tools and TM collar. Initialize MWD tool. Shallow pulse test MWD, 250 gpm, 700 psi. Clean and dress plugs for nukes tool PJSM on handling radio active sources. Load sources in neutron tool, pick up jar, circ sub, xo. TIH to 3,518'. Fill dp, hold PJSM on cutting drilling line. Cut Drilling Line RIH F/ 3,518' - T/ 10,525'. Fill Dp at 7,500' and 10,000'. M/U Top Drive, Rotated through sidetrack section at 10,562' - 10,585', Rotary 40 rpm, pump 200 gpm, 1,000 psi. No Problem. RIH to 10,650', Take survey and confirm correct sidetrack. RIH F/ 10,650 -T/ 11,053'. Wash last 53' to bottom -Total Losses On Trip In The Hole 24 Barrels Directional Drill F/11,053' -T/ 11,070 -Swap Out 580 Barrels Of Flo Pro Mud While Drilling 6 1/8" Hole Section Drilled 6 1/8" Directional Hole By Rotating And Sliding From 11,070' To 11,750' (8,990' TVD) - WOB Rotating 5,000# - 10,000#, RPM 75, Motor RPM 267, Torque Off Bottom 4,000 ft / Ibs - On Bottom 5,000 ft /Ibs, Pump Rate 340 gpm, SPP Off Bottom 2,100 psi, On Bottom 2,320 psi. String Weight Up 190,000#, String Weight Down 160,000#, String Weight Rotating 170,000#. ART - 4.34, AST - 3.02. Drilled 6 1/8" Directional Hole By Rotating And Sliding From 11,750' To 12,245' - WOB Rotating 4,000# - 5,000#, RPM 80, Motor RPM 270, Torque Off Bottom 4,000 ft /Ibs - On Bottom 5,000 ft /Ibs, Pump Rate 350 gpm, SPP Off Bottom 2,250 psi, On Bottom 2,530 psi. String Weight Up 185,000#, String Weight Down 145,000#, String Weight Rotating 165,000#. ART - 3.63 Hrs, AST - 2.32 Hrs. *NOTE* Pumped 11.1 PPG Weighted Sweep Followed Up With Lubricants While Drilling From 11,956' To 12,028' Observed A Decrease Of Torque And Slight Cuttings Increase Printed: 7/5/2006 10:10:38 AM BP EXPLORATION Page 11 of 16 Operations Summary Report Legal Well Name: 15-02 Common Well Name: 15-02 Spud Date: 2/12/1982 Event Name: REENTER+COMPLETE Start: 6/1/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/30/2006 Rig Name: NABORS 27E Rig Number: 27E Date I From - To ; Hours ~ Task Code NPT Phase Description of Operations 6/22/2006 00:00 - 12:00 12.00 DRILL P PROD1 Seen At Shakers 12:00 - 00:00 12.00 DRILL P PROD1 Continue To Drill 6 1/8" Directional Hole By Rotating And Sliding From 12,245' To 12,737' -Toe Well Bore Up Into Base Of Zone 1 B - WOB Rotating 4,000# - 5,000#, RPM 80, Motor RPM 270, Torque Off Bottom 4,500 ft /Ibs - On Bottom 5,500 ft / Ibs, Pump Rate 350 gpm, SPP Off Bottom 2,250 psi, On Bottom 2,430 psi. String Weight Up 190,000#, String Weight Down 145,000#, String Weight Rotating 165,000#. ART - 3.14 Hrs, AST - 5.40 Hrs. 6/23/2006 00:00 - 01:30 1.50 DRILL P PROD1 Drill 6 1/8" Directional Hole By Rotating And Sliding From 12,737' To 12,845' -ART 1.10 Hrs. 01:30 - 03:00 1.50 DRILL P PROD1 Monitor Well Bore (Static) -Take Survey On Bottom -Circulate And Pump 11.3 PPG Weighted Sweep Around Bit And Into The 7" Liner At 350 GPM While Rotating With 80 RPM 03:00 - 05:00 2.00 DRILL P PROD1 Back Ream Out Of The Hole With Full Drilling Rates And 80 RPM From 12,485' To 11,148' With No Problems Production Hole In Good Condition 05:00 - 13:00 8.00 DRILL P PROD1 Madd Pass Log From 11,148' To 10,199' At +/- - 190 FPH, 60 RPM, 350 GPM, 2,160 Psi. -Pull Bit Into 7' Casing Shoe At 10,010' 13:00 - 14:30 1.50 DRILL P PRODi Circulate 25 Barrel Hi-Vis Sweep Surface To Surface While Rotating And Reciprocating Drill String At 8.3 BPM With 2,020 Psi. -Service Top Drive And Traveling Equipment 14:30 - 16:00 1.50 DRILL P PRODi R1H With Directional BHA - No Problems Encountered While Running In The Hole As A Precaution Wash Last Stand To Bottom (NO FILL) 16:00 - 17:30 1.50 DRILL P PROD1 Circulate 11.3 PPG Weighted Sweep Surface To Surface 17:30 - 18:00 0.50 DRILL P PROD1 Monitor Well Bore (Static) -Spot Liner Running Pill 18:00 - 21:00 3.00 DRILL P PROD1 Lay Down 2 Joints Of 4" Drill Pipe - POH From 12,845 To 10,010' Thru Production Hole Section With No Problems - MonitorWell Bore At 7" Casing Shoe (Static) - POH To 8,907' Placing Circulating Sub Below 7" Liner Tie Back Sleeve 21:00 - 23:30 2.50 DRILL P PROD1 Drop Dart And Open Circulation Sub -Pump 25 Barrel Hi-Vis Sweep Surface To Surface At 14 BPM While Rotating And Reciprocating Drill String 90 Feet -Observed Large Amount Of and Cuttings (Sand) At Shakers -Pump Second Hi-Vis Weighted Sweep At 14 BPM Until Shakers Cleaned Up - Monitor Well Bore (Static) -Pump Dry Job -Blow Down Top Drive 23:30 - 00:00 0.50 DRILL P PROD1 POH With 4" Drill Pipe From 8,907' To 7,400' 6/24/2006 00:00 - 03:00 3.00 DRILL P PRODi POH With 4" Drill Pipe From 7,400' To Directional BHA 03:00 - 07:00 4.00 DRILL P PROD1 Hold PJSM -Remove Dart From And Corrosion Ring From BHA -Lay Down Drilling Jars, (2) Flex Collars -Remove Sources -Down Load MWD Tools -Lay Down Flex Drill Collar, MWD Tools, Stab -Drain Motor And Remove 6 1/8" PDC Bit - Lay Down Mud Motor 07:00 - 07:30 0.50 DRILL P PROD1 Clear Off Rig Floor -Directional Drilling BHA Tools 07:30 - 08:00 0.50 BOPSU P RUNPRD Drain BOP Stack -Pull Wear Bushing -Install Test Plug And Energize Lock Down Studs 08:00 - 09:30 1.50 BOPSU P RUNPRD Position 4 1/2" Test Joint Doughnut Below Upper Rams -Rig Up Testing Equipment And Test The Upper Pipe Rams At 250 Psi. Low And 3500 Psi. High -Record On Circle Chart (Good Tests) Printed: 7/5/2006 10:10:38 AM • BP EXPLORATION Page 12 of 16 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-02 15-02 Spud Date: 2/12/1982 REENTER+COMPLETE Start: 6/1/2006 End: NABOBS ALASKA DRILLING I Rig Release: 6/30/2006 NABOBS 27E Rig Number: 27E Date ~ From - To Hours ~ Task Code ~ NPT I_ -1 6/24/2006 109:30 - 10:30 10:30 - 11:30 11:30 - 17:00 1.00 BOPSU P 1.00 CASE P 5.50 CASE P 17:00 - 18:00 1.00 CASE P 18:00 - 18:30 0.50 CASE P 18:30 - 22:30 4.00 CASE P 22:30 - 23:00 I 0.501 CASE I P 23:00 - 00:00 I 1.001 CASE I P 6/25/2006 100:00 - 01:00 01:00 - 01:30 01:30 - 04:00 1.00 CASE P 0.50 CASE P 2.50 CASE P 04:00 - 07:00 3.00 ~ CEMT ~ P Phase ~ Description of Operations RUNPRD Rig Down Testing Equipment -Remove Test Joint -Pull Test Plug -Install Wear Bushing And Energize Lock Down Studs RUNPRD Hold Pre-Job Safety Meeting -Rig Up Casing Power Tongs And Equipment For 4 1/2" Liner RUNPRD Hold Pre-Job Safety Meeting With All Nabors Personal And Vendors -Pick Up And RIH With Shoe Track -Baker Lock Connections To Insert Landing Collar Joint No.3 -Verify Floats Holding -RIH With 72 Joints Of 4 1/2" IBT-M 12.6 Ib. L-80 Casing To 2,959' -Make Up To Mark -Change Out Handling Equipment To 3 1/2" DP Elevators - M / U Baker HMC Liner Hanger, ZXP Packer, Liner Tie Back Sleeve, And Running Tool - Change Out Handling Equipment -Rig Down Casing Tongs - P / U Cross Over, (1) Joint Of 4" Drill Pipe To 3,035' RUNPRD Hold PJSM -Pick Up 15' Pup Joint And Make Up Baker Plug Dropping Head -Torque Same And Lay Down On Pipe Skate RUNPRD RIH w/ 1 Stand 4" Drill Pipe From Mast To 3,130' -Circulate 4 1/2" Liner Volume At 252 GPM With 225 Psi. Liner Up Weight At 82,000# -Down Weight At 78,000# RUNPRD RIH With 72 Joints Of 4 1/2" IBT-M 12.6 Ib. L-80 Liner On 4" Drill Pipe From 3,035' To 10,008' -Fill 4" Drill Pipe Every 20 Stands RUNPRD Circulate Drill Pipe And 4 1/2" Liner Volume At The Following Rates: 84 GPM With 250 Psi. 168 GPM With 340 Psi. 252 GPM With 490 Psi. 4 1/2" Liner & Drill Pipe Slack Off & Pick Up Weights = Up Weight At 170,000 lbs.- Down Weight At 150,000 lbs. Blow Down Top Drive -Install Sensor On Mud manifold For Circle Chart Recorder RUNPRD RIH With 4 1/2" IBT-M 26 Ib. L-80 Liner On 4" Drill Pipe Thru Production Hole Section Filling On The Fly From 10,080' To 11,801' W ith No Problems RUNPRD Continue To RIH With 4 1/2" IBT-M 26 Ib. L-80 Liner On 4" Drill Pipe Thru Production Hole Section Filling On The Fly From 11,801' To 12,841' With No Problems RUNPRD Hold PJSM -Pick Up Baker Plug Droping Head -Install Manifold (Circulating And Wash Up Lines) -Establish Circulation At 2 BPM With 450 Psi -Wash To Bottom At 12,845' RUNPRD Reciprocate Liner And Stage Up Pumping Rates From 2 BPM With 450 Psi. To 6.2 BPM With 955 Psi. -Loose +/- - 21 Barrels Of Fluid During Initial Circulating Process Then Well Bore Stabilized -Circulate And Condition Mud With Full Returns - 4 1/2" Liner & Drill Pipe Slack Off & Pick Up Weights = Up Weight At 187,000 lbs.- Down Weight At 150,000 lbs. 'NOTE' Hold PJSM With All Personal Regarding Cementing And Packer Setting Operations -Test Cementing Lines And Equipment To 4,200 Psi (Good Test) -Then Batch Mix Cement And Mud Push II RUNPRD Pump 5 BBLS Water -Pump 40 BBLS 11.5 PPG Mud Push XT, Followed With 104 BBLS (362 Sacks) 15.8 PPG Class "G" Printed: 7/5/2006 10:10:38 AM • BP EXPLORATION Page 13 of 16 Operations Summary Report Legal Well Name: 15-02 Common Well Name: 15-02 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 27E Date ~ From - To ~ Hours ~ Task ~ Code ~ NPT 6/25/2006 ~ 04:00 - 07:00 3.00 CEMT ( P Spud Date: 2/12/1982 Start: 6/1 /2006 End: I Rig Release: 6/30/2006 Rig Number: 27E Phase Description of Operations RUNPRD Tail Cement With The Following Additives D047 (Antifoam) .2 GAUSK, D065 (Dispersant) .3% BWOC, D600G (Gas Blok) 2.0 GAUSK, 6155 (Retarder) .1 % BWOC At 6.0 BPM -Wash Up Lines To Floor -Drop Dart And Displace With 50 BBLS Perf Pill Followed Up With 8.5 PPG (FLO PRO) Mud At 6.0 BPM With 1050 Psi. -Latch Liner Wiper Plug With 103.8 BBLS Pumped Away -Continue To Displace With Final Circulating Pressure At 1650 Psi. -Bump Plug With A Total Of 148.5 BBLS Pumped To 2,800 Psi. -Slack Off And Verify That The Hanger Is Set -Increase Pressure To 4,200 Psi. To Release From Liner -Bleed Off Pressure And Check Floats (Floats Held) -Cement In Place At 05:24 Hours -Pressure Up Down Drill Pipe To 1,000 Psi. -Pick Up To Release Pack Off From Seals And Expose Running Tool Dogs As Pressure Decreases Ramp Up Pumps To Maximum Rate Circulate Fluid Above Liner Hanger Up Hole 30 BBLS -Reduce Pump Rate To 5.0 BPM Slack Off String With 70,000 lbs. To Set Baker ZXP Packer Rotate And Repeat Process Several Times (Clear Surface Indication That Packer Set) -Increase Pump Rate To Maximum Rate 12.7 BPM At 2,311 Psi. And Continue To Circulate Cement As Planned Back To Surface (1.5 X Bottoms Up) -Top Of Liner At 9,848', Insert Landing Collar At 12,758', Float Collar At 12,799', Float Shoe At 12,845' *NOTE* Reciprocate 4 1/2" Production Liner Until 101 Barrels Into Displacement Then Park And Continue Displacement At 6 BPM With Full Returns - 28 Barrels Of Cement back To Surface 07:00 - 08:30 1.50 CASE P RUNPRD Remove Circulating Line And Manifold -Lay Down Cementing Head And 2 Singles Of 4" Drill Pipe 08:30 - 10:30 2.00 CASE P RUNPRD Displace Well Bore To Seawater At Maximum Pump Rates: Piump Hi-Vis Sweep - 100 Barrels H2O -Seawater (2 X Bottoms Up) 10:30 - 13:30 3.00 CASE P RUNPRD Clean Possom Belly And Under Shakers -Break Down Baker Cementing Head 13:30 - 17:00 3.50 CASE P RUNPRD POH With Baker Liner Running Tool From 9,848' -Laying Down 84 Joints Of 4" Drill Pipe 17:00 - 20:00 3.00 CASE P RUNPRD POH With 4" Drill Pipe Standing Back In The Mast From 7,188' - Observed Traces Of Cement On 4" Drill Pipe W ith 24 Stands Left In The Hole +/- - 2,280' -Cement Sheath On Pipe When 19 Stands Left In The Hole +/- - 1,805' -Clean Drill Pipe When 4 Stands Left In The Hole +/- - 380' 20:00 - 20:30 0.50 CASE P RUNPRD POH With Baker Liner Running Tool -Inspect Running Tool, Brass Pins Were Sheared Indicating That The ZXP Packer Did Set -Lay Down Cross Overs -Make Service Breaks On Running Tool And Lay Down Same 20:30 - 22:30 2.00 BOPSU N CEMT CLEAN Drain BOP Stack -Pull Wear Bushing And Install Test Plug - Install 2 7/8" Ram Blocks In The Top BOP Gate 22:30 - 23:30 1.00 BOPSU N CEMT CLEAN Rig Up BOP Testing Equipment And Test 2 7/8" Rams To 250 Low And 3,500 Psi. High (Good Tests) 23:30 - 00:00 0.50 BOPSU N CEMT CLEAN Rig Down BOP Testing Equipment 6/26/2006 00:00 - 01:00 1.00 BOPSU N CEMT CLEAN Pull Test Plug -Install Wear Bushing -Load Pipe Shed With 2 7/8" PAC Pipe And Mud Motor (SLM Additional Pipe For Clean Printed: 7!5/2006 10:10:38 AM • BP EXPLORATION Operations Summary Report Legal Well Name: 15-02 Common Well Name: 15-02 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 27E Date From - To Hours ' Task I Code ! NPT Start: 6/1 /2006 Rig Release: 6/30/2006 Rig Number: 27E Phase 6/26/2006 00:00 - 01:00 1.00 BOPSUF~N CEMT CLEAN 01:00 - 02:00 1.00 CLEAN I N CEMT CLEAN 02:00 - 03:00 1.00 I CLEAN I N CEMT CLEAN 03:00 - 03:30 I 0.501 CLEAN I N I CEMT I CLEAN 03:30 - 08:30 I 5.001 CLEAN I N I CEMT I CLEAN 08:30 - 09:00 I 0.501 CLEAN I N I CEMT I CLEAN 09:00 - 10:00 I 1.00 CLEAN I N CEMT CLEAN 10:00 - 15:00 I 5.00 I CLEAN I N CEMT CLEAN 15:00 -.16:00 I 1.00 I CLEAN I N I CEMT I CLEAN 16:00 - 16:30 I 0.501 CLEAN I N I SFAL I CLEAN 16:30 - 17:30 I 1.00 I CLEAN I N I SFAL I CLEAN 17:30 - 18:00 I 0.50 CLEAN I N SFAL CLEAN 18:00 - 19:15 ( 1.25 CLEAN I N I SFAL CLEAN 19:15 - 20:15 I 1.00 CLEAN N CEMT CLEAN 20:15 - 22:30 I 2.251 CLEAN I N I CEMT I CLEAN 22:30 - 00:00 I 1.50 I CLEAN I N I CEMT I CLEAN 6/27/2006 100:00 - 02:00 I 2.001 CLEAN I N I CEMT I CLEAN Page 14 of 16 Spud Date: 2/12/1982 End: Description of Operations Out) Test The 4 1/2" Production Liner, 7" Drilling Liner, And The 9 5/8 Casing To 3,500 Psi. For 30 Minutes With Sea Water - Record On Circle Chart (Good Test) -Bring The Handling Tools & Equipment To The Rig Floor For The Clean Out Run Rig Up Power Tongs And Handling Tools To Run 2 7/8" PAC Drill Pipe Pick Up And RIH With 3 3/4" Mill, 3 1/8" Sperry Sun Mud Motor, Circ. Sub To 17' RIH With BHA #9 -Pick Up 94 Joints Of 2 7/8" Pac Drill Pipe To 2,931' - M/U To 3,400 fUlbs Install Cross Overs And Circulate 63 GPM With 250 Psi. - Up And Down Weight At 70K Make Up 7" Casing Scraper, Cross Overs, And Second Circ. Sub To 2,944' RIH With Clean Out Assembly On 4" Drill Pipe From Mast From 2,944' To Top Of 7" Liner At 8,657' - Up Weight At 142K And Down Weight At 129K -Continue To RIH To Top Of 4 1/2" Liner At 9,848' - Up Weight At 158K And Down Weight At 140K - Circulate At 1.5 BPM 344 Psi. -Continue To RIH To 12,752' (With No Problems Or Indication Of Cement) Fill Clean Out String And Establish Circulation With Slight Returns 1.5 BPM With 3,070 Psi. -Work String And Attempt To Increase Circulation -Drop Dart To Open 3 1/8" Circulation Sub - Up Weight 185K -Down Weight 150K -Rotating Weight 170K Top Drive Wash Pipe Cartridge Leaking - POH From 12,745' To 11,890' Change Out The Top Drive Wash Pipe Cartridge And Test Same To 3,500 Psi. Establish Circulation Thru 3 1/8" Circulation Sub At 5.6 BPM With 2,600 Psi. RIH With (1) Stand Of 4" Drill Pipe From Mast, Make Top Drive Connection And Wash Second Stand Down -Repeat Process Thru Production Liner To 12,464' With No Problems - As Precaution Wash At 5.6 BPM With 2,600 Psi. Last Three Stands In The Hole From 12,464' To 12,749' -Started To Take Weight (10K) Reciprocate Clean Out String -Pump 25 Barrel Weighted (10.0 PPG) Hi-Vis Pill, 25 Barrel Perforation Pill, And Chase With 1100 Strokes -Drop Dart -Reciprocate Clean Out String - Pressure Up To Open 4 7/8" Circulation Sub To 4,000 Psi. - Unable To Open Circ. Sub POH With Clean Out String From 12,749' To 9,823' Above 4 1/2" Liner Top Set At 9,848' Rig Up To Reverse Circulate -Reverse Circulate Hi-Vis Sweep At 6 BPM 2,820 Psi. With Mill At 9,823' And 3 1/8" Circ. Sub At 9,806' Reverse Circulate Hi-Vis Sweep At 6 BPM 2,820 Psi. -Pump A Total Of 6,559 Strokes For Surface To Surface Volumes - Open Up The Annular Element And RIH Thru The 4 1/2" Liner To 9,918' With No Problems ('NOTE' The 4 1/2" Liner Top At 9,848') -Observe Fair Amount Of Solids When Reverse Printed: 7/5/2006 10:10:38 AM BP EXPLORATION Page 15 of 16 Operations Summary Report Legal Well Name: 15-02 Common Well Name: 15-02 Spud Date: 2/12/1982 Event Name: REENTER+COMPLETE Start: 6/1/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 6/30/2006 Rig Name: NABOBS 27E Rig Number: 27E Date From - To ;Hours Task i Code NPT Phase Description of Operations 6/27/2006 00:00 - 02:00 2.00 CLEAN N CEMT CLEAN Circulating Sweep Circulate Until Well Bore Cleaned Up. 02:00 - 06:30 4.50 CLEAN N CEMT CLEAN POH With 4" Drill Pipe (Wet) Standing Back In The Mast From 9,918' To 2,944'. 06:30 - 07:00 0.50 CLEAN N CEMT CLEAN B/O and UD XO's and 7" Scraper. R/U Power Tongs to B/O 2-7/8" PAC DP, C/O Elevators to 2-7/8" YZ's and Utilizing Lift Nubbin's to UD DP. 07:00 - 11:00 4.00 CLEAN N CEMT CLEAN POH and VD 49 Joints 2-7/8" PAC DP. B/O Circulating Sub and UD 3-1/8" Motor and 3-3/45" Mill. 11:00 - 12:00 1.00 CLEAN N CEMT CLEAN Clear and Clean Rig Floor. 12:00 - 12:30 0.50 PERFO P OTHCMP C/O Elevators to 3-1/2" DP and R/U to RIH with Perf Gun Assembly. 12:30 - 14:30 2.00 PERFO P OTHCMP P/U and M/U 2-1/2" Schlumberger Perforating Assy Utilizing 6 spf Guns. Total Schlumberger Perforating Assy Length 1,505.32'. 14:30 - 15:00 0.50 PERFO P OTHCMP PJSM; C/O Elevators to 2-7/8" YZ's, R/U Power Tongs. 15:00 - 16:00 1.00 PERFO P OTHCMP PJSM; RIH with 44 Joints 2-7/8" PAC DP from Derrick. 16:00 - 16:30 0.50 PERFO P OTHCMP R/D 2-7/8" Handling Tools and Power Tongs. C/O Elevators to 4" DP 16:30 - 00:00 7.50 PERFO P OTHCMP P/U and M/U XO's and 6" Stablizer. RIH with 4" DP from Derrick to 11,750'. Running Speed 1 min/stand 6/28/2006 00:00 - 01:00 1.00 PERFO P OTHCMP RIH with 4" DP and Tag Up on 4-1/2" Liner Top with 6" Stabilizer at 9,848'. Established Parameters, Up Wt 180K, Dn Wt i60K, Pump 3.8 bpm at 650 psi. P/U to 180K + 6.5' and set Guns on Depth at 12,710'. 01:00 - 02:00 1.00 PERFO P OTHCMP Circulated at 3.8 bpm, 650 psi. Held PJSM with Schlumberger Personnel and Rig Crew. Closed Annular Preventer and Opened Kill Line. Pressured Up to 400 psi. Waited 1 min. Increased Pressre to 600 psi. Waited 1 min. Bled Pressure to 0 psi. Waited 1-1/2min. Pressured Up to 1,200 psi. Waited 2 min. Bled Pressure Down to 0 psi. Guns Fired After 5 min. Monitored Well- Well Took Initial 5 bbls then Went Static. Seawater 8.5 ppg. 02:00 - 03:30 1.50 PERFO P OTHCMP POH with 4" DP. Racked Back 30 Stands DP to get Above 4-1/2" Liner Top. Monitor Well Static. 03:30 - 10:30 7.00 PERFO P OTHCMP POH Lay Down 4" DP F/ 9,849' - T/ 2,875'. 10:30 - 11:00 0.50 PERFO P OTHCMP B/O and UD XO's and 6" Stabilizer. CIO Elevators to 2-7/8" YZ's. 11:00 - 13:30 2.50 PERFO P OTHCMP POH and UD 2-7/8" PAC DP. 13:30 - 14:00 0.50 PERFO P OTHCMP Held PJSM with Schlumberger Personnel and Rig Crew, C/O Elevators to 3-1/2" DP. 14:00 - 20:00 6.00 PERFO P OTHCMP POH with Schlumberger 2-1/2" Spent Perforating Guns and UD Same in 20' Sections. All Shots Fired. 20:00 - 21:00 1.00 PERFO P OTHCMP R/D Perf Gun Handling Equipment and Tools. Clear and Clean Rig Floor. 21:00 - 22:00 1.00 PERFO P OTHCMP RIH with 30 Stand 4" DP from Derrick 22:00 - 00:00 2.00 PERFO P OTHCMP POH and UD 4" DP 6/29/2006 00:00 - 01:30 1.50 PERFO P OTHCMP POH and VD Excess 4" DP from Derrick 01:30 - 02:00 0.50 BOPSU P RUNCMP PJSM, Drain Stack, Remove Wear Ring. 02:00 - 03:30 1.50 BOPSU P RUNCMP Change Top Rams to 3-1/2" x 6" Variable's. 03:30 - 04:00 0.50 BOPSU P RUNCMP Test 3-1/2" x 6" Variable Rams to 250 / 3,500 psi for 5 min each. Test Witnessed by BP WSL. 04:00 - 04:30 0.50 BOPSU P RUNCMP Pull Test Plug. 04:30 - 05:00 0.50 BUNCO P RUNCMP P/U Tubing Hanger and Make Dummy Run to Tubing Spool. Printed: 7/5/2006 10:10:38 AM BP EXPLORATION Page 16 of 16 Operations Summary Report Legal Well Name: 15-02 Common Well Name: 15-02 Spud Date: 2/12/1982 Event Name: REENTER+COMPLETE Start: 6/1/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 6/30/2006 Rig Name:- NABOBS 27E Rig Number: 27E Date ;From - To I Hours ~I Task Code ~ NPT Phase ; Description of Operations 6/29/2006 05:00 - 06:00 1.00 06:00 - 23:00 17.00 23:00 - 00:00 I 1.00 6/30/2006 100:00 - 01:30 I 1.50 01:30 - 02:00 I 0.50 02:00 - 05:30 I 3.50 05:30 - 06:00 I 0.50 06:00 - 08:30 I 2.50 08:30 - 09:00 0.50 BOPSU P 09:00 - 12:00 3.00 BOPSU P 12:00 - 16:00 4.00 BOPSU P 16:00 - 17:00 1.00 WHSUR P 17:00 - 18:00 1.00 WHSUR P 18:00 - 18:30 0.50 WHSUR P 18:30 - 19:30 1.00 WHSUR P 19:30 - 20:00 0.501 W HSUR P 20:00 - 22:00 2.001 WHSUR P 22:00 - 22:30 0.50 WHSUR P 22:30 - 23:30 1.00 WHSUR P 23:30 - 00:00 0.50 WHSUR P RUNCMP PJSM, R/U Tubing Handling, Power Tongs and Torque Turn Equipment RUNCMP P/U and RIH with 4-1/2" WLEG & "XN" Nipple Assy, "X" Nipple Assy, 4-1/2" x 7" Packer Assy, "X" Nipple Assy and 4-1/2" 12.6# TC-II Tubing, GLM's Set at 8,393', 7,001', 5,152' and 3,172', Last 'X" Nipple Assy. set at 2,197'. RUNCMP P/U Joint # 232 and #233, Circulate Down at 3 bpm at 100 psi. Tag Top of 4-1/2" Liner at 9,840', NO GO at 9,851'. Did Not Obsereve Pressure Increase When Entering 7" Tie Back Sleave RUNCMP UD Joints # 233, #232 and # 231. P/U Pup Joints 9.81', 9.73', 7.78', 5.78', 3.68'. P/U Joint # 231. P/U and M/U Hanger and Landing Joint. Land Hanger in Tubing Spool. WLEG Set at 9,845', 5' Inside 4-1/2" x 7" Tie-Back Sleave. RILDS. String Up Wt. 150K, String Dn Wt 135K. RUNCMP R/U Circulating Lines on Rig Floor and to 4-1/2" x 9-5/8" Annulus RUNCMP Reverse Circulated at 3 bpm, 485 psi, Down 4-1/2" x 9-5/8" Annulus Taking Returns Up Tubing. Pumped 335 bbls Seawater Treated with Corrosion Inhibitor Followed by 160 bbls Clean Seawater. RUNCMP R/D Circulating Line. Drop 1-7/8" Packer Setting Ball and Rod. Removed Landing Joint. B/O XO's and UD Same. RUNCMP Pressured Up on Tubing to 3,500 psi. to Set Packer. Held 30 min. Bled Pressure Down to 1,500 psi. Pressured Up on Annulus to 3,500 psi. Held 30 min. Bled Annulus Pressure Down to 0 psi. Bled Tubing Pressure Down to 0 psi. Pressured Upon Annulus and Sheared DCR Valve at 2,300 psi. Circulated at 1 bpm F/ Annulus -T/ Tubing at 130 psi. Circulated at 1 bpm F/ Tubing - T/ Annulus at 130 psi. OTHCMP R/D Circulating Lines, Drain Stack and Installed TWC OTHCMP PJSM, R/D Kill, Choke Lines and Flowline. Remove Drilling Riser. OTHCMP N/D BOPE's OTHCMP N/U Adapter Flange and Test to 5,000 psi. OTHCMP N/U Tree OTHCMP R/U Test Lines and Test Tree to 5,000 psi OTHCMP R/U DSM Lubricator and Pull TWC. Installed VR Plug Dead IA Valve OTHCMP PJSM, R/U Hot Oil to IA with Return Line from Tree to Slop Tank. Connect U-Tube Line From IA to Tubing OTHCMP Pump 152 bbls Diesel with Hot Oil at 2 bpm, 800 psi Down IA Taking Returns from Tubing to Slope Tank. OTHCMP U-Tube Diesel from IA to Tubing OTHCMP R/U DSM Lubricator and Installed BPV. R/D Lunricator OTHCMP Install Tree Cap, Removed Double Annulus Valves. RELEASED RIG AT 2400 HRS, 6/30/06 Printed: 7/5/2006 10:10:38 AM Halliburton Com an P Y Survey Report __ _ __ Company: BP Amoco - - Date: 6!27/2006 Time: 16:22:04 Page: 1 Field: Prudhoe Bay Co-ordinatc(1'E) Keference: Well: 15-02, Tru e Nonh Site: PB DS 15 Vertical (TVD) Reference: 15-02B: 66.5 Well: 15-02 Section (VS) Refer ence: Well (O.OON,O.OOE,264.09Azi) Wellpath: 15-026 Survey Calculation Method: Minimum Curvature Db: Oracle Field: Prudhoe Ba y North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Cla rke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Well: 15-02 Slot Name: 02 15-02 Well Position: +N/-S 1210.77 ft Northing: 5960046.65 ft Latitude: 70 17 47.144 N +E/-W -45.55 ft Fasting : 676223 .05 ft Longitude: 148 34 22.541 W Position Uncertainty: 0.00 ft Wellpath: 15-026 Drilled From: 15-026PB1 50029206970202 Tie-on Depth: 10507.50 ft Current Datum: 15-0 26: Height 66.50 ft Above System Datum: Mean Sea Level Magnetic Data: 6/5/2006 Declination: 24.57 deg Field Strength: 57611 nT Mag Dip Angle: 80.91 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 33.60 0.00 0.00 264.09 Survey Program for Definitive Wellpath Date: 6/27/2006 Validated: Yes Version: 14 Actual From To Survey Toolcode Tool Name ft ft 103.50 8778.50 15-02_Gyrodata (103.50-9039.60 GYD-CT-CMS Gyrodata cont.casing m/s 8794.00 10507.50 15-026P6 1 IIFR+MS+SAG (8794.00 MWD+IFR+MS MWD +IFR + Multi Sta tion 10562.00 12799.13 15-026 IIFR+MS+SAG (10562.00-1 MWD+IFR+MS MWD +IFR + Multi Sta tion ~ Survey ', >VtD Inc! .dim TVD Sys TVD N/S E!N' MapN MapE Toul '~ ft deg deg ft ft ft ft ft ft 33.60 0.00 0.00 33.60 -32.90 0.00 0.00 5960046.65 676223.05 TIE LINE 103.50 0.19 123.37 103.50 37.00 -0.06 0.10 5960046.59 676223.15 GYD-CT-CMS 203.50 0.37 241.38 203.50 137.00 -0.31 -0.05 5960046.34 676223.01 GYD-CT-CMS 303.50 0.43 229.99 303.50 237.00 -0.71 -0.62 5960045.93 676222.45 GYD-CT-CMS 403.50 0.48 217.50 403.49 336.99 -1.28 -1.16 5960045.34 676221.92 GYD-CT-CMS 503.50 0.41 178.21 503.49 436.99 -1.97 -1.41 5960044.65 676221.69 GYD-CT-CMS 603.50 0.35 140.11 603.49 536.99 -2.56 -1.20 5960044.06 676221.91 GYD-CT-CMS 703.50 0.38 136.60 703.49 636.99 -3.04 -0.77 5960043.60 676222.35 GYD-CT-CMS 803.50 0.41 133.72 803.48 736.98 -3.52 -0.29 5960043.12 676222.84 GYD-CT-CMS 903.50 0.40 146.67 903.48 836.98 -4.06 0.16 5960042.59 676223.31 GYD-CT-CMS 1003.50 0.38 157.47 1003.48 936.98 -4.66 0.48 5960042.00 676223.64 GYD-CT-CMS 1103.50 0.42 112.00 1103.48 1036.98 -5.10 0.95 5960041.57 676224.12 GYD-CT-CMS 1203.50 0.47 68.24 1203.47 1136.97 -5.09 1.67 5960041.60 676224.84 GYD-CT-CMS 1303.50 0.61 68.71 1303.47 1236.97 -4.74 2.55 5960041.97 676225.71 GYD-CT-CMS 1403.50 0.75 68.22 1403.46 1336.96 -4.31 3.65 5960042.43 676226.80 GYD-CT-CMS 1503.50 0.71 42.16 1503.46 1436.96 -3.61 4.67 5960043.15 676227.81 GYD-CT-CMS 1603.50 0.67 16.47 1603.45 1536.95 -2.59 5.25 5960044.19 676228.36 GYD-CT-CMS 1703.50 0.55 0.45 1703.44 1636.94 -1.55 5.42 5960045.23 676228.51 GYD-CT-CMS 1803.50 0.43 345.86 1803.44 1736.94 -0.70 5.34 5960046.07 676228.40 GYD-CT-CMS 1903.50 0.37 9.45 1903.44 1836.94 -0.02 5.30 5960046.75 676228.35 GYD-CT-CMS 2003.50 0.30 41.67 2003.43 1936.93 0.49 5.52 5960047.27 676228.56 GYD-CT-CMS 2103.50 0.20 298.85 2103.43 2036.93 0.77 5.55 5960047.55 676228.58 GYD-CT-CMS 2203.50 0.25 59.69 2203.43 2136.93 0.97 5.58 5960047.75 676228.61 GYD-CT-CMS 2303.50 0.27 107.37 2303.43 2236.93 1.01 5.99 5960047.80 676229.02 GYD-CT-CMS 2403.50 0.28 189.63 2403.43 2336.93 0.70 6.18 5960047.49 676229.21 GYD-CT-CMS 2503.50 0.49 193.57 2503.43 2436.93 0.04 6.04 5960046.83 676229.08 GYD-CT-CMS 2603.50 0.55 182.02 2603.43 2536.93 -0.86 5.92 5960045.93 676228.99 GYD-CT-CMS 2703.50 0.86 171.14 2703.42 2636.92 -2.08 6.02 5960044.72 676229.12 GYD-CT-CMS Halliburton Com an P Y Survey Report ~I ~~ ~~ Company: BP Amoco Field: Prudhoe Bay Site: PB DS 15 Well: 15-02 Wellpath: 15-02B Su r~ ev ---- -- MD -ucl ft deg _ Azim deg - _ TVD ft _. SysTVD ft Date: 6/27/2006 Time: 16:22:04 Page, Z Co-ordinateQYE) Reference: Well: 15-02, True North Vertical (TVD) Reference: 15-02B: 66.5 Section (VS) Keference: Well (O.OON,O.OOE,264.09Azi) Survey Calculation Method: Minimum Curvature Db: Oracle - _ _ _---- - I N/S E/W MapIV MapE 'T'ool l ft ft ft ft 2803.50 1.78 204.95 2803.39 2736.89 -4.23 5.48 5960042.55 676228.63 GYD-CT-CMS 2903.50 4.41 226.52 2903.24 2836.74 -8.28 2.03 5960038.42 676225.28 GYD-CT-CMS 3003.50 6.54 230.19 3002.78 2936.28 -14.57 -5.13 5960031.96 676218.26 GYD-CT-CMS 3103.50 8.69 230.35 3101.89 3035.39 -23.04 -15.32 5960023.26 676208.27 GYD-CT-CMS 3203.50 12.62 229.05 3200.15 3133.65 -35.03 -29.40 5960010.95 676194.48 GYD-CT-CMS 3303.50 15.13 228.69 3297.22 3230.72 -50.80 -47.45 5959994.75 676176.80 GYD-CT-CMS 3403.50 17.67 230.01 3393.15 3326.65 -69.17 -68.89 5959975.88 676155.81 GYD-CT-CMS 3428.50 18.18 229.49 3416.93 3350.43 -74.15 -74.76 5959970.78 676150.05 GYD-CT-CMS 3453.50 18.80 229.69 3440.64 3374.14 -79.29 -80.80 5959965.50 676144.14 GYD-CT-CMS 3478.50 19.26 230.08 3464.28 3397.78 -84.54 -87.03 5959960.10 676138.03 GYD-CT-CMS 3503.50 19.77 230.21 3487.84 3421.34 -89.89 -93.44 5959954.60 676131.75 GYD-CT-CMS 3528.50 20.39 230.30 3511.32 3444.82 -95.38 -100.04 5959948.96 676125.28 GYD-CT-CMS 3553.50 21.04 230.50 3534.70 3468.20 -101.01 -106.86 5959943.17 676118.60 GYD-CT-CMS 3578.50 22.03 230.78 3557.96 3491.46 -106.83 -113.95 5959937.18 676111.64 GYD-CT-CMS 3603.50 22.88 230.98 3581.06 3514.56 -112.86 -121.36 5959930.99 676104.38 GYD-CT-CMS 3628.50 23.51 231.13 3604.04 3537.54 -119.05 -129.02 5959924.62 676096.87 GYD-CT-CMS 3653.50 24.15 231.39 3626.91 3560.41 -125.37 -136.90 5959918.12 676089.14 GYD-CT-CMS 3678.50 24.87 231.59 3649.66 3583.16 -131.82 -145.01 5959911.47 676081.18 GYD-CT-CMS 3703.50 25.55 231.90 3672.28 3605.78 -138.42 -153.37 5959904.68 676072.97 GYD-CT-CMS 3728.50 26.06 231.82 3694.78 3628.28 -145.14 -161.93 5959897.76 676064.57 GYD-CT-CMS 3753.50 26.67 232.07 3717.18 3650.68 -151.98 -170.68 5959890.72 676056.00 GYD-CT-CMS 3778.50 27.34 232.13 3739.46 3672.96 -158.95 -179.63 5959883.54 676047.20 GYD-CT-CMS 3803.50 28.27 232.22 3761.57 3695.07 -166.11 -188.84 5959876.17 676038.16 GYD-CT-CMS 3828.50 28.94 232.33 3783.52 3717.02 -173.43 -198.31 5959868.63 676028.87 GYD-CT-CMS 3853.50 29.79 232.32 3805.30 3738.80 -180.92 -208.01 5959860.91 676019.35 GYD-CT-CMS 3878.50 30.82 232.38 3826.89 3760.39 -188.63 -218.00 5959852.98 676009.54 GYD-CT-CMS 3903.50 31.36 232.44 3848.30 3781.80 -196.50 -228.23 5959844.86 675999.50 GYD-CT-CMS 3928.50 32.12 232.37 3869.56 3803.06 -204.53 -238.65 5959836.60 675989.27 GYD-CT-CMS 3953.50 33.14 232.34 3890.61 3824.11 -212.76 -249.33 5959828.12 675978.80 GYD-CT-CMS 3978.50 33.83 232.33 3911.46 3844.96 -221.19 -260.24 5959819.44 675968.08 GYD-CT-CMS 4003.50 34.87 232.45 3932.10 3865.60 -229.80 -271.42 5959810.57 675957.11 GYD-CT-CMS 4028.50 35.73 232.39 3952.51 3886.01 -238.61 -282.87 5959801.49 675945.87 GYD-CT-CMS 4053.50 36.39 232.45 3972.72 3906.22 -247.58 -294.53 5959792.25 675934.42 GYD-CT-CMS 4078.50 37.19 232.46 3992.74 3926.24 -256.70 -306.40 5959782.85 675922.77 GYD-CT-CMS 4103.50 37.83 232.49 4012.57 3946.07 -265.98 -318.47 5959773.30 675910.92 GYD-CT-CMS 4128.50 38.49 232.54 4032.22 3965.72 -275.38 -330.73 5959763.61 675898.89 GYD-CT-CMS 4153.50 39.02 232.58 4051.72 3985.22 -284.89 -343.16 5959753.81 675886.69 GYD-CT-CMS 4178.50 40.03 232.78 4071.00 4004.50 -294.54 -355.81 5959743.87 675874.27 GYD-CT-CMS 4203.50 40.72 232.87 4090.05 4023.55 -304.32 -368.71 5959733.79 675861.60 GYD-CT-CMS 4228.50 41.72 233.13 4108.85 4042.35 -314.24 -381.87 5959723.57 675848.68 GYD-CT-CMS 4253.50 42.70 233.23 4127.37 4060.87 -324.30 -395.31 5959713.19 675835.47 GYD-CT-CMS 4278.50 43.82 233.33 4145.58 4079.08 -334.54 -409.05 5959702.63 675821.98 GYD-CT-CMS 4303.50 44.27 233.36 4163.55 4097.05 -344.92 -422.99 5959691.93 675808.29 GYD-CT-CMS 4328.50 44.51 233.30 4181.41 4114.91 -355.36 -437.02 5959681.16 675794.51 GYD-CT-CMS 4353.50 44.65 233.36 4199.22 4132.72 -365.84 -451.09 5959670.35 675780.69 GYD-CT-CMS 4378.50 44.61 233.42 4217.01 4150.51 -376.32 -465.19 5959659.55 675766.84 GYD-CT-CMS 4403.50 44.60 233.46 4234.81 4168.31 -386.78 -479.29 5959648.77 675752.99 GYD-CT-CMS 4428.50 44.76 233.35 4252.58 4186.08 -397.26 -493.41 5959637.96 675739.13 GYD-CT-CMS 4453.50 44.92 233.38 4270.31 4203.81 -407.77 -507.55 5959627.11 675725.23 GYD-CT-CMS 4478.50 45.13 233.33 4287.98 4221.48 -418.33 -521.74 5959616.23 675711.29 GYD-CT-CMS 4503.50 45.17 233.32 4305.61 4239.11 -428.92 -535.96 5959605.31 675697.33 GYD-CT-CMS 4528.50 45.24 233.44 4323.23 4256.73 -439.50 -550.20 5959594.40 675683.35 GYD-CT-CMS Halliburton Com an P Y Survey Report Company: BP Amoco Date: 6/27/2006 Time: 16:22:04 Page: 3 Field: Pru dhoe Bay Co-ordinate(NE) Reference: Well: 15-02, Tru e North '~ Site: PB DS 15 Verti cal (TVD) Reference: 15-026: 66.5 Well: 15-02 Section (VS) Reference: Well (O.OON,O.O OE,264.09Azi) '~ Wcllpath: 15-02B Survey Calculati on Method: Minimum Curvature Db: Orade Survc~' MD Incl Azim "IT'D Sys "~VD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 4553.50 45.23 233.52 4340.83 4274.33 -450.06 -564.46 5959583.51 675669.33 GYD-CT-CMS 4578.50 45.27 233.64 4358.43 4291.93 -460.60 -578.75 5959572.63 675655.30 GYD-CT-CMS 4603.50 45.47 233.80 4376.00 4309.50 -471.13 -593.09 5959561.77 675641.21 GYD-CT-CMS 4628.50 45.33 233.77 4393.55 4327.05 -481.65 -607.45 5959550.92 675627.10 GYD-CT-CMS 4653.50 45.45 233.82 4411.11 4344.61 -492.16 -621.81 5959540.08 675612.99 GYD-CT-CMS 4678.50 45.70 233.85 4428.61 4362.11 -502.70 -636.23 5959529.21 675598.83 GYD-CT-CMS 4703.50 45.67 233.84 4446.07 4379.57 -513.25 -650.67 5959518.32 675584.63 GYD-CT-CMS 4728.50 45.71 233.75 4463.53 4397.03 -523.82 -665.10 5959507.42 675570.45 GYD-CT-CMS 4753.50 45.83 233.78 4480.97 4414.47 -534.40 -679.55 5959496.49 675556.26 GYD-CT-CMS 4778.50 45.76 233.84 4498.40 4431.90 -544.99 -694.02 5959485.58 675542.05 GYD-CT-CMS 4803.50 45.73 233.76 4515.85 4449.35 -555.56 -708.47 5959474.67 675527.85 GYD-CT-CMS 4828.50 45.69 233.87 4533.31 4466.81 -566.13 -722.91 5959463.77 675513.66 GYD-CT-CMS 4853.50 45.85 233.77 4550.75 4484.25 -576.70 -737.37 5959452.86 675499.45 GYD-CT-CMS 4878.50 45.10 233.69 4568.28 4501.78 -587.25 -751.74 5959441.98 675485.33 GYD-CT-CMS 4903.50 45.25 233.80 4585.90 4519.40 -597.73 -766.04 5959431.16 675471.29 GYD-CT-CMS 4928.50 45.43 233.75 4603.47 4536.97 -608.24 -780.38 5959420.32 675457.19 GYD-CT-CMS 4953.50 45.58 233.77 4620.99 4554.49 -618.78 -794.77 5959409.44 675443.06 GYD-CT-CMS 4978.50 45.27 233.93 4638.54 4572.04 -629.29 -809.15 5959398.60 675428.93 GYD-CT-CMS 5003.50 45.29 234.00 4656.13 4589.63 -639.74 -823.51 5959387.82 675414.82 GYD-CT-CMS 5028.50 45.44 234.05 4673.70 4607.20 -650.19 -837.91 5959377.04 675400.67 GYD-CT-CMS 5053.50 45.31 234.19 4691.26 4624.76 -660.62 -852.32 5959366.27 675386.50 GYD-CT-CMS 5078.50 45.17 234.27 4708.86 4642.36 -670.99 -866.73 5959355.56 675372.35 GYD-CT-CMS 5103.50 45.27 234.41 4726.47 4659.97 -681.34 -881.15 5959344.88 675358.18 GYD-CT-CMS 5128.50 45.37 234.45 4744.05 4677.55 -691.68 -895.60 5959334.21 675343.97 GYD-CT-CMS 5153.50 45.49 234.61 4761.59 4695.09 -702.01 -910.11 5959323.54 675329.71 GYD-CT-CMS 5178.50 45.47 234.84 4779.12 4712.62 -712.31 -924.66 5959312.91 675315.40 GYD-CT-CMS 5203.50 45.47 235.08 4796.65 4730.15 -722.54 -939.25 5959302.33 675301.06 GYD-CT-CMS 5228.50 45.57 235.17 4814.17 4747.67 -732.74 -953.89 5959291.80 675286.67 GYD-CT-CMS 5253.50 45.47 235.30 4831.69 4765.19 -742.91 -968.54 5959281.28 675272.26 GYD-CT-CMS 5278.50 45.50 235.41 4849.21 4782.71 -753.04 -983.21 5959270.81 675257.83 GYD-CT-CMS 5303.50 45.19 235.45 4866.79 4800.29 -763.13 -997.85 5959260.38 675243.43 GYD-CT-CMS 5328.50 45.33 235.46 4884.38 4817.88 -773.20 -1012.48 5959249.97 675229.05 GYD-CT-CMS 5353.50 45.21 235.65 4901.98 4835.48 -783.25 -1027.12 5959239.58 675214.64 GYD-CT-CMS 5378.50 45.28 235.77 4919.58 4853.08 -793.25 -1041.79 5959229.24 675200.21 GYD-CT-CMS 5403.50 45.16 236.08 4937.19 4870.69 -803.19 -1056.49 5959218.96 675185.75 GYD-CT-CMS 5428.50 45.46 236.12 4954.77 4888.27 -813.11 -1071.24 5959208.70 675171.24 GYD-CT-CMS 5453.50 45.73 236.22 4972.26 4905.76 -823.05 -1086.08 5959198.41 675156.64 GYD-CT-CMS 5478.50 45.72 236.47 4989.72 4923.22 -832.97 -1100.98 5959188.15 675141.98 GYD-CT-CMS 5503.50 45.82 236.79 5007.15 4940.65 -842.82 -1115.94 5959177.95 675127.25 GYD-CT-CMS 5528.50 45.91 237.01 5024.56 4958.06 -852.62 -1130.97 5959167.80 675112.46 GYD-CT-CMS 5553.50 46.00 237.33 5041.94 4975.44 -862.36 -1146.07 5959157.71 675097.59 GYD-CT-CMS 5578.50 46.20 237.42 5059.28 4992.78 -872.08 -1161.24 5959147.64 675082.65 GYD-CT-CMS 5603.50 46.40 237.57 5076.55 5010.05 -881.79 -1176.48 5959137.58 675067.64 GYD-CT-CMS 5628.50 46.39 237.60 5093.79 5027.29 -891.49 -1191.76 5959127.52 675052.59 GYD-CT-CMS 5653.50 46.59 237.64 5111.01 5044.51 -901.20 -1207.08 5959117.45 675037.51 GYD-CT-CMS 5678.50 46.16 237.78 5128.25 5061.75 -910.87 -1222.38 5959107.43 675022.45 GYD-CT-CMS 5703.50 46.11 237.90 5145.58 5079.08 -920.46 -1237.63 5959097.48 675007.42 GYD-CT-CMS 5728.50 46.41 237.96 5162.86 5096.36 -930.05 -1252.94 5959087.53 674992.34 GYD-CT-CMS 5753.50 46.52 238.12 5180.08 5113.58 -939.65 -1268.32 5959077.58 674977.20 GYD-CT-CMS 5778.50 46.77 238.30 5197.24 5130.74 -949.22 -1283.77 5959067.65 674961.97 GYD-CT-CMS 5803.50 47.12 238.38 5214.31 5147.81 -958.81 -1299.32 5959057.70 674946.66 GYD-CT-CMS 5828.50 47.23 238.51 5231.31 5164.81 -968.41 -1314.94 5959047.74 674931.26 GYD-CT-CMS 5853.50 47.47 238.52 5248.24 5181.74 -978.01 -1330.62 5959037.77 674915.81 GYD-CT-CMS Halliburton Com an P Y Survey Report ~ Company: BP Amoco Field: Prudhoe Bay Date: 6/27/2006 Time: 16:22:04 Page: 4 Co-ordinate(NE) Reference: Well: 15-02, True North Site: PB DS 15 Vertical (TVD) Reference: 15-026: 66.5 Well: 15- 02 Section (VS) Refer ence: Weli (O.ODN,O.OOE,264.09Azi) Wellpath: 15- 028 Survey Calculation Method: Minimum Curva ture Db: Oracfe Survcv MD lncl Azim T~'D Sys TVD N/S El~Y MapN MapE Tool ft deg deg ft ft ft ft ft ft 5878.50 47.72 238.60 5265.10 5198.60 -987.64 -1346.37 5959027.78 674900.29 GYD-CT-CMS 5903.50 47.53 238.56 5281.95 5215.45 -997.27 -1362.13 5959017.78 674884.76 GYD-CT-CMS 5928.50 47.63 238.64 5298.82 5232.32 -1006.88 -1377.88 5959007.80 674869.24 GYD-CT-CMS 5953.50 47.70 238.65 5315.65 5249.15 -1016.50 -1393.67 5958997.82 674853.69 GYD-CT-CMS 5978.50 47.92 238.77 5332.44 5265.94 -1026.12 -1409.49 5958987.83 674838.09 GYD-CT-CMS 6003.50 48.26 238.89 5349.14 5282.64 -1035.75 -1425.41 5958977.83 674822.40 GYD-CT-CMS 6028.50 48.21 239.14 5365.79 5299.29 -1045.35 -1441.40 5958967.86 674806.65 GYD-CT-CMS 6053.50 48.30 239.32 5382.44 5315.94 -1054.89 -1457.43 5958957.95 674790.85 GYD-CT-CMS 6078.50 48.69 239.38 5399.01 5332.51 -1064.44 -1473.53 5958948.03 674774.97 GYD-CT-CMS 6103.50 48.84 239.46 5415.49 5348.99 -1074.00 -1489.72 5958938.09 674759.02 GYD-CT-CMS 6128.50 48.84 239.75 5431.94 5365.44 -1083.52 -1505.95 5958928.19 674743.01 GYD-CT-CMS 6153.50 49.05 239.89 5448.36 5381.86 -1093.00 -1522.25 5958918.33 674726.94 GYD-CT-CMS 6178.50 49.29 240.14 5464.70 5398.20 -1102.45 -1538.64 5958908.50 674710.78 GYD-CT-CMS 6203.50 49.36 240.29 5481.00 5414.50 -1111.87 -1555.09 5958898.69 674694.56 GYD-CT-CMS 6228.50 49.30 240.52 5497.29 5430.79 -1121.24 -1571.58 5958888.95 674678.29 GYD-CT-CMS 6253.50 49.37 240.53 5513.58 5447.08 -1130.57 -1588.09 5958879.23 674662.01 GYD-CT-CMS 6278.50 49.71 240.63 5529.81 5463.31 -1139.91 -1604.66 5958869.50 674645.66 GYD-CT-CMS 6303.50 49.73 240.74 5545.97 5479.47 -1149.25 -1621.29 5958859.78 674629.26 GYD-CT-CMS 6328.50 50.16 240.80 5562.06 5495.56 -1158.59 -1637.99 5958850.05 674612.78 GYD-CT-CMS 6353.50 50.30 240.81 5578.05 5511.55 -1167.97 -1654.76 5958840.28 674596.24 GYD-CT-CMS 6378.50 50.07 240.96 5594.06 5527.56 -1177.31 -1671.54 5958830.55 674579.68 GYD-CT-CMS 6403.50 49.91 240.99 5610.13 5543.63 -1186.60 -1688.28 5958820.87 674563.16 GYD-CT-CMS 6428.50 49.91 241.06 5626.23 5559.73 -1195.87 -1705.01 5958811.21 674546.66 GYD-CT-CMS 6453.50 49.77 240.98 5642.35 5575.85 -1205.12 -1721.73 5958801.57 674530.16 GYD-CT-CMS 6478.50 49.59 241.11 5658.53 5592.03 -1214.35 -1738.40 5958791.95 674513.71 GYD-CT-CMS 6503.50 49.66 241.06 5674.72 5608.22 -1223.56 -1755.08 5958782.36 674497.26 GYD-CT-CMS 6528.50 49.30 241.15 5690.97 5624.47 -1232.74 -1771.71 5958772.79 674480.84 GYD-CT-CMS 6553.50 49.06 241.00 5707.31 5640.81 -1241.89 -1788.27 5958763.25 674464.50 GYD-CT-CMS 6578.50 48.95 240.98 5723.71 5657.21 -1251.04 -1804.77 5958753.72 674448.22 GYD-CT-CMS 6603.50 48.66 241.07 5740.17 5673.67 -1260.16 -1821.23 5958744.22 674431.98 GYD-CT-CMS 6628.50 48.45 241.18 5756.72 5690.22 -1269.21 -1837.64 5958734.79 674415.79 GYD-CT-CMS 6653.50 48.43 241.25 5773.31 5706.81 -1278.21 -1854.04 5958725.40 674399.61 GYD-CT-CMS 6678.50 48.10 241.17 5789.95 5723.45 -1287.20 -1870.39 5958716.04 674383.48 GYD-CT-CMS 6703.50 47.83 241.31 5806.69 5740.19 -1296.13 -1886.66 5958706.72 674367.42 GYD-CT-CMS 6728.50 47.91 241.36 5823.46 5756.96 -1305.03 -1902.93 5958697.45 674351.36 GYD-CT-CMS 6753.50 47.57 241.52 5840.27 5773.77 -1313.87 -1919.18 5958688.23 674335.32 GYD-CT-CMS 6778.50 47.51 241.62 5857.15 5790.65 -1322.65 -1935.40 5958679.07 674319.31 GYD-CT-CMS 6803.50 47.42 241.72 5874.05 5807.55 -1331.40 -1951.62 5958669.95 674303.31 GYD-CT-CMS 6828.50 47.13 241.75 5891.01 5824.51 -1340.09 -1967.79 5958660.88 674287.34 GYD-CT-CMS 6853.50 47.19 241.79 5908.01 5841.51 -1348.76 -1983.94 5958651.83 674271.40 GYD-CT-CMS 6878.50 47.46 241.73 5924.96 5858.46 -1357.46 -2000.14 5958642.76 674255.42 GYD-CT-CMS 6903.50 47.19 241.73 5941.90 5875.40 -1366.17 -2016.33 5958633.67 674239.44 GYD-CT-CMS 6928.50 47.09 241.80 5958.91 5892.41 -1374.83 -2032.47 5958624.63 674223.50 GYD-CT-CMS 6953.50 46.84 241.82 5975.97 5909.47 -1383.47 -2048.58 5958615.62 674207.61 GYD-CT-CMS 6978.50 46.91 241.74 5993.06 5926.56 -1392.10 -2064.65 5958606.62 674191.74 GYD-CT-CMS 7003.50 46.97 241.74 6010.13 5943.63 -1400.74 -2080.74 5958597.60 674175.86 GYD-CT-CMS 7028.50 46.79 241.80 6027.22 5960.72 -1409.38 -2096.82 5958588.59 674159.99 GYD-CT-CMS 7053.50 46.98 241.79 6044.30 5977.80 -1418.00 -2112.90 5958579.59 674144.11 GYD-CT-CMS 7078.50 46.78 241.70 6061.39 5994.89 -1426.64 -2128.98 5958570.58 674128.24 GYD-CT-CMS 7103.50 46.61 241.73 6078.54 6012.04 -1435.26 -2145.00 5958561.59 674112.43 GYD-CT-CMS 7128.50 46.35 241.68 6095.75 6029.25 -1443.85 -2160.96 5958552.62 674096.68 GYD-CT-CMS 7153.50 46.46 241.58 6112.99 6046.49 -1452.46 -2176.89 5958543.65 674080.95 GYD-CT-CMS ~~ Halliburton Com an P Y Survey Report Company: BP Amoco llate: 6/27/2006 'l'ime: 16:22:04 Page: 5 ~ Field: Pru dhoe Bay Co-ordinate(NE) Reference: Well: 15-02, Tru e North Site: PB DS 15 Vertical (TVD) Reference: 15-02B: 66.5 Well: 15-02 Section (VS) Refer ence: Well (O.OON,OAOE,264.09Azi) Wellpath: 15- 02B Surve v Calculation Method: Minimum Curva ture Db: Oracle Survev MD Incl Azim TVD Sys TVD N/S E1W MapN MapE Tool ft deg deg ft ft ft ft ft ft 7178.50 46.90 241.54 6130.14 6063.64 -1461.12 -2192.88 5958534.61 674065.17 GYD-CT-CMS 7203.50 46.78 241.53 6147.24 6080.74 -1469.81 -2208.92 5958525.55 674049.35 GYD-CT-CMS 7228.50 46.54 241.53 6164.40 6097.90 -1478.48 -2224.90 5958516.51 674033.57 GYD-CT-CMS 7253.50 46.38 241.54 6181.62 6115.12 -1487.11 -2240.83 5958507.50 674017.85 GYD-CT-CMS 7278.50 46.46 241.60 6198.86 6132.36 -1495.74 -2256.76 5958498.51 674002.13 GYD-CT-CMS 7303.50 46.20 241.58 6216.12 6149.62 -1504.34 -2272.66 5958489.54 673986.43 GYD-CT-CMS 7328.50 45.88 241.53 6233.47 6166.97 -1512.91 -2288.49 5958480.60 673970.81 GYD-CT-CMS 7353.50 46.03 241.51 6250.85 6184.35 -1521.48 -2304.28 5958471.66 673955.22 GYD-CT-CMS 7378.50 45.95 241.41 6268.22 6201.72 -1530.07 -2320.08 5958462.70 673939.64 GYD-CT-CMS 7403.50 45.85 241.42 6285.62 6219.12 -1538.66 -2335.84 5958453.74 673924.08 GYD-CT-CMS 7428.50 45.83 241.47 6303.04 6236.54 -1547.23 -2351.59 5958444.81 673908.53 GYD-CT-CMS 7453.50 45.49 241.42 6320.51 6254.01 -1555.78 -2367.30 5958435.89 673893.03 GYD-CT-CMS 7478.50 45.46 241.35 6338.04 6271.54 -1564.32 -2382.95 5958426.99 673877.59 GYD-CT-CMS 7503.50 45.25 241.34 6355.61 6289.11 -1572.85 -2398.55 5958418.10 673862.19 GYD-CT-CMS 7528.50 45.00 241.23 6373.25 6306.75 -1581.36 -2414.09 5958409.23 673846.85 GYD-CT-CMS 7553.50 44.77 241.20 6390.96 6324.46 -1589.85 -2429.55 5958400.37 673831.60 GYD-CT-CMS 7578.50 44.66 241.24 6408.73 6342.23 -1598.32 -2444.97 5958391.55 673816.38 GYD-CT-CMS 7603.50 44.40 241.19 6426.55 6360.05 -1606.76 -2460.34 5958382.75 673801.22 GYD-CT-CMS 7628.50 44.25 241.13 6444.43 6377.93 -1615.19 -2475.64 5958373.96 673786.12 GYD-CT-CMS 7653.50 44.12 241.19 6462.36 6395.86 -1623.59 -2490.90 5958365.20 673771.06 GYD-CT-CMS 7678.50 43.75 241.16 6480.36 6413.86 -1631.96 -2506.10 5958356.49 673756.07 GYD-CT-CMS 7703.50 43.64 241.14 6498.44 6431.94 -1640.29 -2521.23 5958347.80 673741.14 GYD-CT-CMS 7728.50 43.53 241.11 6516.55 6450.05 -1648.61 -2536.32 5958339.13 673726.25 GYD-CT-CMS 7753.50 43.32 241.13 6534.71 6468.21 -1656.91 -2551.37 5958330.48 673711.40 GYD-CT-CMS 7778.50 43.22 241.18 6552.91 6486.41 -1665.18 -2566.38 5958321.86 673696.59 GYD-CT-CMS 7803.50 42.94 241.07 6571.17 6504.67 -1673.43 -2581.33 5958313.27 673681.83 GYD-CT-CMS 7828.50 42.64 241.21 6589.52 6523.02 -1681.62 -2596.20 5958304.73 673667.16 GYD-CT-CMS 7853.50 42.53 241.18 6607.92 6541.42 -1689.78 -2611.03 5958296.23 673652.53 GYD-CT-CMS 7878.50 42.20 241.18 6626.39 6559.89 -1697.90 -2625.79 5958287.77 673637.97 GYD-CT-CMS 7903.50 42.12 241.30 6644.93 6578.43 -1705.97 -2640.50 5958279.35 673623.45 GYD-CT-CMS 7928.50 41.82 241.46 6663.51 6597.01 -1713.98 -2655.17 5958271.00 673608.97 GYD-CT-CMS 7953.50 41.15 241.32 6682.24 6615.74 -1721.91 -2669.71 5958262.73 673594.62 GYD-CT-CMS 7978.50 41.09 241.36 6701.07 6634.57 -1729.79 -2684.14 5958254.51 673580.38 GYD-CT-CMS 8003.50 40.99 241.33 6719.93 6653.43 -1737.66 -2698.54 5358246.31 673566.17 GYD-CT-CMS 8028.50 40.70 241.36 6738.84 6672.34 -1745.51 -2712.89 5958238.13 673552.01 GYD-CT-CMS 8053.50 40.47 241.35 6757.83 6691.33 -1753.30 -2727.16 5958230.00 673537.92 GYD-CT-CMS 8078.50 40.24 241.38 6776.88 6710.38 -1761.06 -2741.37 5958221.91 673523.90 GYD-CT-CMS 8103.50 39.94 241.52 6796.01 6729.51 -1768.75 -2755.51 5958213.89 673509.94 GYD-CT-CMS 8128.50 39.80 241.52 6815.19 6748.69 -1776.40 -2769.60 5958205.92 673496.04 GYD-CT-CMS 8153.50 39.54 241.41 6834.44 6767.94 -1784.02 -2783.62 5958197.97 673482.20 GYD-CT-CMS 8178.50 39.27 241.55 6853.75 6787.25 -1791.60 -2797.56 5958190.07 673468.44 GYD-CT-CMS 8203.50 39.18 241.33 6873.12 6806.62 -1799.16 -2811.45 5958182.19 673454.74 GYD-CT-CMS 8228.50 38.90 241.36 6892.54 6826.04 -1806.71 -2825.27 5958174.32 673441.10 GYD-CT-CMS 8253.50 38.62 241.44 6912.03 6845.53 -1814.20 -2839.01 5958166.50 673427.54 GYD-CT-CMS 8278.50 38.61 241.34 6931.57 6865.07 -1821.67 -2852.71 5958158.71 673414.02 GYD-CT-CMS 8303.50 38.35 241.32 6951.14 6884.64 -1829.13 -2866.35 5958150.93 673400.55 GYD-CT-CMS 8328.50 38.00 241.31 6970.79 6904.29 -1836.55 -2879.91 5958143.20 673387.18 GYD-CT-CMS 8353.50 37.96 241.30 6990.50 6924.00 -1843.94 -2893.41 5958135.50 673373.86 GYD-CT-CMS 8378.50 37.53 241.27 7010.26 6943.76 -1851.29 -2906.83 5958127.84 673360.62 GYD-CT-CMS 8403.50 37.39 241.34 7030.11 6963.61 -1858.59 -2920.16 5958120.22 673347.45 GYD-CT-CMS 8428.50 37.31 241.24 7049.98 6983.48 -1865.88 -2933.47 5958112.63 673334.33 GYD-CT-CMS 8453.50 37.06 241.28 7069.90 7003.40 -1873.14 -2946.72 5958105.06 673321.25 GYD-CT-CMS 8478.50 37.22 241.18 7089.83 7023.33 -1880.41 -2959.95 5958097.48 673308.20 GYD-CT-CMS Halliburton Com an P Y Survey Report Company: BP Amoco Date 6/27/2006 'l'ime 16:22:04 Page: Field: Pru dhoe Bay Co-ordinate(NE) Reference: Well: 15-02, Tru e North Site: PB DS 15 Verti cal (TVD) Reference: 15-02B: 66.5 Well: 15- 02 Section (VS) Refer ence: Well (O.OON,O.O OE,264.09Azi) Wellpath: 15- 02B Survey Calculation Method: Minimum Curvature Ub: Oracle Survey .- MD Incl Azim _ _ '1'Vll __ .- Sys TVD N1S E/~'V ---- MapN - MapE Tool ft deg deg ft ft ft ft ft ft 8503.50 37.49 241.23 7109.70 7043.20 -1887.71 -2973.24 5958089.87 673295.08 GYD-CT-CMS 8528.50 37.58 241.21 7129.53 7063.03 -1895.05 -2986.59 5958082.22 673281.91 GYD-CT-CMS 8553.50 37.46 241.16 7149.35 7082.85 -1902.38 -2999.93 5958074.58 673268.74 GYD-CT-CMS 8578.50 37.39 241.23 7169.21 7102.71 -1909.70 -3013.24 5958066.95 673255.61 GYD-CT-CMS 8603.50 37.34 241.24 7189.08 7122.58 -1917.01 -3026.54 5958059.33 673242.48 GYD-CT-CMS 8628.50 37.27 241.16 7208.96 7142.46 -1924.30 -3039.82 5958051.73 673229.38 GYD-CT-CMS 8653.50 37.13 241.13 7228.88 7162.38 -1931.60 -3053.06 5958044.12 673216.32 GYD-CT-CMS 8678.50 37.15 241.17 7248.81 7182.31 -1938.88 -3066.28 5958036.53 673203.27 GYD-CT-CMS 8703.50 37.13 241.04 7268.73 7202.23 -1946.18 -3079.49 5958028.93 673190.23 GYD-CT-CMS 8728.50 36.98 241.05 7288.69 7222.19 -1953.47 -3092.68 5958021.33 673177.23 GYD-CT-CMS 8753.50 36.89 241.30 7308.67 7242.17 -1960.71 -3105.84 5958013.78 673164.24 GYD-CT-CMS 8778.50 36.79 241.41 7328.68 7262.18 -1967.90 -3118.99 5958006.29 673151.26 GYD-CT-CMS 8794.00 36.62 241.41 7341.10 7274.60 -1972.33 -3127.13 5958001.67 673143.23 MWD+IFR+MS 8871.84 34.96 237.30 7404.25 7337.75 -1995.49 -3166.29 5957977.60 673104.62 MWD+IFR+MS 8965.92 34.17 231.89 7481.74 7415.24 -2026.37 -3209.77 5957945.71 673061.88 MWD+IFR+MS 9060.61 31.77 225.96 7561.20 7494.70 -2060.12 -3248.63 5957911.06 673023.83 MWD+IFR+MS 9155.26 32.84 217.95 7641.23 7574.73 -2097.70 -3282.34 5957872.70 672991.01 MWD+IFR+MS 9249.97 34.55 212.78 7720.05 7653.55 -2140.54 -3312.68 5957829.17 672961.68 MWD+IFR+MS 9343.25 33.66 213.14 7797.28 7730.78 -2184.43 -3341.13 5957784.63 672934.27 MWD+IFR+MS 9438.39 34.97 212.98 7875.86 7809.36 -2229.38 -3370.39 5957739.01 672906.07 MWD+IFR+MS 9533.33 35.74 212.42 7953.29 7886.79 -2275.61 -3400.07 5957692.10 672877.49 MWD+IFR+MS 9627.76 35.02 211.57 8030.28 7963.78 -2321.97 -3429.04 5957645.07 672849.62 MWD+IFR+MS 9722.00 34.39 211.39 8107.76 8041.26 -2367.73 -3457.06 5957598.67 672822.68 MWD+IFR+MS 9816.69 33.85 216.20 8186.16 8119.66 -2411.85 -3486.57 5957553.87 672794.22 MWD+IFR+MS 9911.30 33.35 216.59 8264.97 8198.47 -2453.99 -3517.63 5957511.01 672764.15 MWD+IFR+MS 9959.72 32.88 217.10 8305.52 8239.02 -2475.16 -3533.49 5957489.48 672748.79 MWD+IFR+MS 10007.01 33.13 221.43 8345.19 8278.69 -2495.09 -3549.79 5957469.17 672732.97 MWD+IFR+MS 10035.59 30.77 224.20 8369.44 8302.94 -2506.19 -3560.06 5957457.84 672722.96 MWD+IFR+MS 10067.14 29.53 236.38 8396.74 8330.24 -2516.29 -3572.17 5957447.46 672711.09 MWD+IFR+MS 10097.71 26.78 246.67 8423.71 8357.21 -2523.20 -3584.78 5957440.26 672698.65 MWD+IFR+MS 10129.76 24.14 257.47 8452.66 8386.16 -2527.48 -3597.81 5957435.67 672685.72 MWD+IFR+MS 10161.59 23.71 257.78 8481.75 8415.25 -2530.25 -3610.42 5957432.61 672673.18 MWD+IFR+MS 10193.78 24.35 260.05 8511.16 8444.66 -2532.77 -3623.28 5957429.79 672660.38 MWD+IFR+MS 10225.47 27.79 265.01 8539.62 8473.12 -2534.54 -3637.08 5957427.70 672646.63 MWD+IFR+MS 10257.00 29.27 273.66 8567.33 8500.83 -2534.69 -3652.11 5957427.20 672631.61 MWD+IFR+MS 10288.72 28.45 282.85 8595.13 8528.63 -2532.51 -3667.22 5957429.02 672616.45 MWD+IFR+MS 10319.93 29.41 294.32 8622.46 8555.96 -2527.70 -3681.46 5957433.50 672602.10 MWD+IFR+MS 10351.56 30.11 298.66 8649.92 8583.42 -2520.69 -3695.50 5957440.17 672587.90 MWD+IFR+MS 10380.91 29.40 298.41 8675.40 8608.90 -2513.73 -3708.30 5957446.83 672574.95 MWD+IFR+MS 10412.41 30.19 306.58 8702.75 8636.25 -2505.33 -3721.46 5957454.92 672561.59 MWD+IFR+MS 10444.31 29.83 306.63 8730.38 8663.88 -2495.82 -3734.27 5957464.13 672548.56 MWD+IFR+MS 10475.62 31.77 308.80 8757.27 8690.77 -2486.00 -3746.95 5957473.64 672535.66 MWD+IFR+MS 10507.50 35.23 313.21 8783.85 8717.35 -2474.44 -3760.19 5957484.88 672522.15 MWD+IFR+MS 10562.00 42.55 320.30 8826.27 8759.77 -2449.46 -3783.47 5957509.32 672498.30 MWD+IFR+MS 10602.57 41.03 319.39 8856.51 8790.01 -2428.79 -3800.90 5957529.57 672480.39 MWD+IFR+MS 10632.80 45.03 317.03 8878.61 8812.11 -2413.43 -3814.65 5957544.60 672466.28 MWD+IFR+MS 10665.38 49.47 315.33 8900.72 8834.22 -2396.18 -3831.22 5957561.46 672449.31 MWD+IFR+MS 10697.60 54.28 313.99 8920.61 8854.11 -2378.38 -3849.25 5957578.83 672430.87 MWD+IFR+MS 10726.81 58.53 313.13 8936.76 8870.26 -2361.62 -3866.88 5957595.17 672412.85 MWD+IFR+MS 10760.06 63.65 312.80 8952.83 8886.33 -2341.79 -3888.17 5957614.49 672391.10 MWD+IFR+MS 10791.92 68.85 311.77 8965.66 8899.16 -2322.18 -3909.74 5957633.59 672369.08 MWD+IFR+MS 10821.68 73.81 314.12 8975.19 8908.69 -2302.97 -3930.37 5957652.31 672348.01 MWD+IFR+MS Halliburton Com an P Y Survey Report Company: BP Amoco Date: 6/27/2006 Time: 16:22:04 Page: 7 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 15-02, True North Site: PB DS 15 Vertical (TVD) Reference: 15-028: 66.5 Well: 15-02 Section (VS) Keference: WeII (O.OON,O.OOE,264.09Azi) Wcllpath: 15-02B Survey Calculation Method: Minimum Curvature Db: Oracle Survc~ __ __._- _ _ ---- M11D [nd Azim TVll Sys TVD N1S E1W MapN MapE Tool ft deg deg ft ft ft ft ft ft ______, 10854.09 78.70 314.81 8982.88 8916.38 -2280.93 -3952.83 5957673.82 672325.04 MWD+IFR+MS 10886.08 83.52 316.81 8987.83 8921.33 -2258.27 -3974.85 5957695.95 672302.50 MWD+IFR+MS 10916.25 87.79 318.36 8990.11 8923.61 -2236.06 -3995.13 5957717.68 672281.70 MWD+IFR+MS 10947.30 90.08 323.48 8990.69 8924.19 -2211.97 -4014.69 5957741.30 672261.58 MWD+IFR+MS 10981.37 90.44 328.89 8990.54 8924.04 -2183.68 -4033.65 5957769.14 672241.97 MWD+IFR+MS 11011.22 90.94 336.45 8990.18 8923.68 -2157.18 -4047.34 5957795.31 672227.66 MWD+IFR+MS 11035.97 90.06 336.56 8989.96 8923.46 -2134.48 -4057.21 5957817.76 672217.27 MWD+IFR+MS 11083.12 88.52 339.25 8990.54 8924.04 -2090.81 -4074.94 5957861.01 672198.52 MWD+IFR+MS 11130.80 88.04 338.72 8991.97 8925.47 -2046.32 -4092.03 5957905.08 672180.39 MWD+IFR+MS 11176.44 87.85 339.33 8993.61 8927.11 -2003.73 -4108.36 5957947.28 672163.07 MWD+IFR+MS 11226.66 87.36 339.91 8995.71 8929.21 -1956.69 -4125.83 5957993.88 672144.50 MWD+IFR+MS 11275.89 88.77 340.12 8997.37 8930.87 -1910.46 -4142.65 5958039.71 672126.60 MWD+IFR+MS 11321.13 89.33 340.00 8998.12 8931.62 -1867.94 -4158.07 5958081.86 672110.19 MWD+IFR+MS 11368.56 90.50 338.53 8998.19 8931.69 -1823.58 -4174.86 5958125.81 672092.36 MWD+IFR+MS 11414.57 90.32 340.16 8997.86 8931.36 -1780.53 -4191.09 5958168.46 672075.13 MWD+IFR+MS 11459.94 89.58 339.57 8997.90 8931.40 -1737.93 -4206.71 5958210.68 672058.52 MWD+IFR+MS 11509.34 89.64 339.52 8998.24 8931.74 -1691.65 -4223.97 5958256.54 672040.17 MWD+IFR+MS 11558.96 90.32 338.59 8998.26 8931.76 -1645.31 -4241.71 5958302.45 672021.36 MWD+IFR+MS 11604.32 91.74 339.46 8997.44 8930.94 -1602.96 -4257.94 5958344.40 672004.13 MWD+IFR+MS 11648.66' 93.03 339.47 8995.60 8929.10 -1561.48 -4273.48 5958385.51 671987.63 MWD+IFR+MS 11698.42 92.79 338.97 8993.07 8926.57 -1515.01 -4291.12 5958431.54 671968.91 MWD+IFR+MS 11745.45 91.80 339.19 8991.19 8924.69 -1471.12 -4307.89 5958475.03 671951.11 MWD+IFR+MS 11792.14 91.74 340.57 8989.74 8923.24 -1427.30 -4323.95 5958518.45 671934.04 MWD+IFR+MS 11840.63 90.94 340.67 8988.61 8922.11 -1381.57 -4340.03 5958563.79 671916.88 MWD+IFR+MS 11886.20 92.17 341.72 8987.37 8920.87 -1338.45 -4354.72 5958606.55 671901.19 MWD+IFR+MS 11931.14 92.23 341.01 8985.65 8919.15 -1295.90 -4369.07 5958648.75 671885.85 MWD+IFR+MS 11981.27 93.59 340.18 8983.10 8916.60 -1248.68 -4385.70 5958695.57 671868.12 MWD+IFR+MS 12031.57 93.10 340.15 8980.17 8913.67 -1201.44 -4402.74 5958742.39 671849.98 MWD+IFR+MS 12076.20 91.74 338.00 8978.28 8911.78 -1159.80 -4418.66 5958783.65 671833.08 MWD+IFR+MS 12125.25 92.05 335.98 8976.66 8910.16 -1114.68 -4437.82 5958828.30 671812.87 MWD+IFR+MS 12170.19 92.11 336.83 8975.03 8908.53 -1073.52 -4455.80 5958869.02 671793.93 MWD+IFR+MS 12219.50 91.19 334.65 8973.61 8907.11 -1028.59 -4476.05 5958913.46 671772.64 MWD+IFR+MS 12265.19 92.54 331.86 8972.12 8905.62 -987.81 -4496.60 5958953.74 671751.14 MWD+IFR+MS 12310.09 92.85 331.26 8970.01 8903.51 -948.38 -4517.96 5958992.67 671728.86 MWD+IFR+MS 12358.57 92.42 333.64 8967.78 8901.28 -905.44 -4540.36 5959035.06 671705.47 MWD+IFR+MS 12407.55 93.29 330.44 8965.34 8898.84 -862.24 -4563.29 5959077.71 671681.53 MWD+IFR+MS 12453.15 93.72 330.74 8962.56 8896.06 -822.59 -4585.64 5959116.82 671658.26 MWD+IFR+MS 12494.63 93.29 329.72 8960.02 8893.52 -786.65 -4606.19 5959152.27 671636.86 MWD+IFR+MS 12547.91 92.55 330.61 8957.31 8890.81 -740.49 -4632.67 5959197.79 671609.32 MWD+IFR+MS 12595.88 93.84 328.42 8954.63 8888.13 -699.22 -4656.96 5959238.48 671584.06 MWD+IFR+MS 12642.27 93.72 326.71 8951.57 8885.07 -660.16 -4681.79 5959276.95 671558.33 MWD+IFR+MS 12693.38 93.22 325.26 8948.48 8881.98 -617.87 -4710.33 5959318.55 671528.81 MWD+IFR+MS 12736.10 93.22 323.53 8946.08 8879.58 -583.19 -4735.16 5959352.63 671503.17 MWD+IFR+MS 12799.13 92.85 321.78 8942.74 8876.24 -533.16 -4773.34 5959401.76 671463.83 MWD+IFR+MS 12845.00 92.85 321.78 8940.46 8873.96 -497.16 -4801.68 5959437.07 671434.66 BLIND Halliburton Com an P Y Survey Report Company: BP Amoco Date: 6/27!2006 Timc: 16:19:51 Page: I Field: Prudhoe Bay Co -ordinate(NE) R eference: WeII. 15-02, Tru e North Sitc: PB DS 15 Well: 15-02 Vertical (TVD) Reference: 15-02B: 66.5 Section (VS) Reference: Well (O.OON,O.O OE,242.52Azi) Wellpath: 15-026PB1 Survey Calculation Method: Minimum Curva ture Db: Oracle Field: Prudhoe Bay _ - _ _.._. North Slope UNITED STATES Map System:US State Plane Coordin ate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Cla rke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea L evel Geomagnetic Model: bggm2005 Well: 15-02 Slot Name: 02 15-02 Well Position: +N/-S 1210.77 ft Northing: .5960046.65 ft Latitude: 70 17 47.144 N +E/-W -45.55 ft Easti ng : 676223.05 ft Longitude: 148 34 22.541 W Position Uncertainty: 0.00 ft Wellpath: 15-02BP81 Drilled From: 15-02 50029206970271 Tie-on Depth: 8778.50 ft Current Datum: 15-026: Height 66.50 ft Above System Datum: Mean Sea Level Magnetic Data: 6/5/2006 Declination: 24.57 deg Field Strength: 57611 nT Mag Dip Angle: 80.91 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 33.60 0.00 0.00 242.52 Survey Program for Definitive Wellpath Date: 6/27/2006 Validated: Yes Version: 19 Actual From To Survey Toolcode Tool Name ft ft 103.50 8778.50 15-02_Gyrodata (10 3.50-9039.60 GYD-CT-CMS Gyrodata cont.casing m/s 8794.00 10980.21 15-026PB 1 IIFR+MS+SAG (8794 .00 MWD+IFR+MS MWD +IFR + Multi Station Survey MD Inc! Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 33.60 0.00 0.00 33.60 -32.90 0.00 0.00 5960046.65 676223.05 TIE LINE 103.50 0.19 123.37 103.50 37.00 -0.06 0.10 5960046.59 676223.15 GYD-CT-CMS 203.50 0.37 241.38 203.50 137.00 -0.31 -0.05 5960046.34 676223.01 GYD-CT-CMS 303.50 0.43 229.99 303.50 237.00 -0.71 -0.62 5960045.93 676222.45 GYD-CT-CMS 403.50 0.48 217.50 403.49 336.99 -1.28 -1.16 5960045.34 676221.92 GYD-CT-CMS 503.50 0.41 178.21 503.49 436.99 -1.97 -1.41 5960044.65 676221.69 GYD-CT-CMS 603.50 0.35 140.11 603.49 536.99 -2.56 -1.20 5960044.06 676221.91 GYD-CT-CMS 703.50 0.38 136.60 703.49 636.99 -3.04 -0.77 5960043.60 676222.35 GYD-CT-CMS 803.50 0.41 133.72 803.48 736.98 -3.52 -0.29 5960043.12 676222.84 GYD-CT-CMS 903.50 0.40 146.67 903.48 836.98 -4.06 0.16 5960042.59 676223.31 GYD-CT-CMS 1003.50 0.38 157.47 1003.48 936.98 -4.66 0.48 5960042.00 676223.64 GYD-CT-CMS 1103.50 0.42 112.00 1103.48 1036.98 -5.10 0.95 5960041.57 676224.12 GYD-CT-CMS 1203.50 0.47 68.24 1203.47 1136.97 -5.09 1.67 5960041.60 676224.84 GYD-CT-CMS 1303.50 0.61 68.71 1303.47 1236.97 -4.74 2.55 5960041.97 676225.71 GYD-CT-CMS 1403.50 0.75 68.22 1403.46 1336.96 -4.31 3.65 5960042.43 676226.80 GYD-CT-CMS 1503.50 0.71 42.16 1503.46 1436.96 -3.61 4.67 5960043.15 676227.81 GYD-CT-CMS 1603.50 0.67 16.47 1603.45 1536.95 -2.59 5.25 5960044.19 676228.36 GYD-CT-CMS 1703.50 0.55 0.45 1703.44 1636.94 -1.55 5.42 5960045.23 676228.51 GYD-CT-CMS 1803.50 0.43 345.86 1803.44 1736.94 -0.70 5.34 5960046.07 676228.40 GYD-CT-CMS 1903.50 0.37 9.45 1903.44 1836.94 -0.02 5.30 5960046.75 676228.35 GYD-CT-CMS 2003.50 0.30 41.67 2003.43 1936.93 0.49 5.52 5960047.27 676228.56 GYD-CT-CMS 2103.50 0.20 298.85 2103.43 2036.93 0.77 5.55 5960047.55 676228.58 GYD-CT-CMS 2203.50 0.25 59.69 2203.43 2136.93 0.97 5.58 5960047.75 676228.61 GYD-CT-CMS 2303.50 0.27 107.37 2303.43 2236.93 1.01 5.99 5960047.80 676229.02 GYD-CT-CMS 2403.50 0.28 189.63 2403.43 2336.93 0.70 6.18 5960047.49 676229.21 GYD-CT-CMS 2503.50 0.49 193.57 2503.43 2436.93 0.04 6.04 5960046.83 676229.08 GYD-CT-CMS 2603.50 0.55 182.02 2603.43 2536.93 -0.86 5.92 5960045.93 676228.99 GYD-CT-CMS 2703.50 0.86 171.14 2703.42 2636.92 -2.08 6.02 5960044.72 676229.12 GYD-CT-CMS 2803.50 1.78 204.95 2803.39 2736.89 -4.23 5.48 5960042.55 676228.63 GYD-CT-CMS ± ~ • Halliburton Com an i P Y Survey Report Company: BP Amoco Uate: 6/27/2006 Time: 16:19:51 Page: 2 Field: Pru dhoe Bay Co-ordinate(NE) Reference: Well: 15-02, Tru e North Site: PB DS 15 Vertical (TVD) Reference: 15-026: 66.5 Well: 15-02 Section (VS) Reference: Well (O.OON,O.O OE,242.52Azi) Wellpath: 15-026P61 Surve y Calculation Ntethod: Minimum Curvature Db: Oracle ~ Survev MD incl Azim TVD Sys TVD N/S E!W MapN MapE Tool ft deg deg ft ft ft ft ft ft 2903.50 4.41 226.52 2903.24 2836.74 -8.28 2.03 5960038.42 676225.28 GYD-CT-CMS 3003.50 6.54 230.19 3002.78 2936.28 -14.57 -5.13 5960031.96 676218.26 GYD-CT-CMS 3103.50 8.69 230.35 3101.89 3035.39 -23.04 -15.32 5960023.26 676208.27 GYD-CT-CMS 3203.50 12.62 229.05 3200.15 3133.65 -35.03 -29.40 5960010.95 676194.48 GYD-CT-CMS 3303.50 15.13 228.69 3297.22 3230.72 -50.80 -47.45 5959994.75 676176.80 GYD-CT-CMS 3403.50 17.67 230.01 3393.15 3326.65 -69.17 -68.89 5959975.88 676155.81 GYD-CT-CMS 3428.50 18.18 229.49 3416.93 3350.43 -74.15 -74.76 5959970.78 676150.05 GYD-CT-CMS 3453.50 18.80 229.69 3440.64 3374.14 -79.29 -80.80 5959965.50 676144.14 GYD-CT-CMS 3478.50 19.26 230.08 3464.28 3397.78 -84.54 -87.03 5959960.10 676138.03 GYD-CT-CMS 3503.50 19.77 230.21 3487.84 3421.34 -89.89 -93.44 5959954.60 676131.75 GYD-CT-CMS 3528.50 20.39 230.30 3511.32 3444.82 -95.38 -100.04 5959948.96 676125.28 GYD-CT-CMS 3553.50 21.04 230.50 3534.70 3468.20 -101.01 -106.86 5959943.17 676118.60 GYD-CT-CMS 3578.50 22.03 230.78 3557.96 3491.46 -106.83 -113.95 5959937.18 676111.64 GYD-CT-CMS 3603.50 22.88 230.98 3581.06 3514.56 -112.86 -121.36 5959930.99 676104.38 GYD-CT-CMS 3628.50 23.51 231.13 3604.04 3537.54 -119.05 -129.02 5959924.62 676096.87 GYD-CT-CMS 3653.50 24.15 231.39 3626.91 3560.41 -125.37 -136.90 5959918.12 676089.14 GYD-CT-CMS 3678.50 24.87 231.59 3649.66 3583.16 -131.82 -145.01 5959911.47 676081.18 GYD-CT-CMS 3703.50 25.55 231.90 3672.28 3605.78 -138.42 -153.37 5959904.68 676072.97 GYD-CT-CMS 3728.50 26.06 231.82 3694.78 3628,28 -145.14 -161.93 5959897.76 676064.57 GYD-CT-CMS 3753.50 26.67 232.07 3717.18 3650.68 -151.98 -170.68 5959890.72 676056.00 GYD-CT-CMS 3778.50 27.34 232.13 3739.46 3672,96 -158.95 -179.63 5959883.54 676047.20 GYD-CT-CMS 3803.50 28.27 232.22 3761.57 3695.07 -166.11 -188.84 5959876.17 676038.16 GYD-CT-CMS 3828.50 28.94 232.33 3783.52 3717.02 -173.43 -198.31 5959868.63 676028.87 GYD-CT-CMS 3853.50 29.79 232.32 3805.30 3738.80 -180.92 -208.01 5959860.91 676019.35 GYD-CT-CMS 3878.50 30.82 232.38 3826.89 3760.39 -188.63 -218.00 5959852.98 676009.54 GYD-CT-CMS 3903.50 31.36 232.44 3848.30 3781.80 -196.50 -228.23 5959844.86 675999.50 GYD-CT-CMS 3928.50 32.12 232.37 3869.56 3803.06 -204.53 -238.65 5959836.60 675989.27 GYD-CT-CMS 3953.50 33.14 232.34 3890.61 3824.11 -212.76 -249.33 5959828.12 675978.80 GYD-CT-CMS 3978.50 33.83 232.33 3911.46 3844.96 -221.19 -260.24 5959819.44 675968.08 GYD-CT-CMS 4003.50 34.87 232.45 3932.10 3865.60 -229.80 -271.42 5959810.57 675957.11 GYD-CT-CMS 4028.50 35.73 232.39 3952.51 3886.01 -238.61 -282.87 5959801.49 675945.87 GYD-CT-CMS 4053.50 36.39 232.45 3972.72 3906.22 -247.58 -294.53 5959792.25 675934.42 GYD-CT-CMS 4078.50 37.19 232.46 3992.74 3926.24 -256.70 -306.40 5959782.85 675922.77 GYD-CT-CMS 4103.50 37.83 232.49 4012.57 3946.07 -265.98 -318.47 5959773.30 675910.92 GYD-CT-CMS 4128.50 38.49 232.54 4032.22 3965.72 -275.38 -330.73 5959763.61 675898.89 GYD-CT-CMS 4153.50 39.02 232.58 4051.72 3985.22 -284.89 -343.16 5959753.81 675886.69 GYD-CT-CMS 4178.50 40.03 232.78 4071.00 4004.50 -294.54 -355.81 5959743.87 675874.27 GYD-CT-CMS 4203.50 40.72 232.87 4090.05 4023.55 -304.32 -368.71 5959733.79 675861.60 GYD-CT-CMS 4228.50 41.72 233.13 4108.85 4042.35 -314.24 -381.87 5959723.57 675848.68 GYD-CT-CMS 4253.50 42.70 233.23 4127.37 4060.87 -324.30 -395.31 5959713.19 675835.47 GYD-CT-CMS 4278.50 43.82 233.33 4145.58 4079.08 -334.54 -409.05 5959702.63 675821.98 GYD-C7-CMS 4303.50 44.27 233.36 4163.55 4097.05 -344.92 -422.99 5959691.93 675808.29 GYD-CT-CMS 4328.50 44.51 233.30 4181.41 4114.91 -355.36 -437.02 5959681.16 675794.51 GYD-CT-CMS 4353.50 44.65 233.36 4199.22 4132.72 -365.84 -451.09 5959670.35 675780.69 GYD-CT-CMS 4378.50 44.61 233.42 4217.01 4150.51 -376.32 -465.19 5959659.55 675766.84 GYD-CT-CMS 4403.50 44.60 233.46 4234.81 4168.31 -386.78 -479.29 5959648.77 675752.99 GYD-CT-CMS 4428.50 44.76 233.35 4252.58 4186.08 -397.26 -493.41 5959637.96 675739.13 GYD-CT-CMS 4453.50 44.92 233.38 4270.31 4203.81 -407.77 -507.55 5959627.11 675725.23 GYD-CT-CMS 4478.50 45.13 233.33 4287.98 4221.48 -418.33 -521.74 5959616.23 675711.29 GYD-CT-CMS 4503.50 45.17 233.32 4305.61 4239.11 -428.92 -535.96 5959605.31 675697.33 GYD-CT-CMS 4528.50 45.24 233.44 4323.23 4256.73 -439.50 -550.20 5959594.40 675683.35 GYD-CT-CMS 4553.50 45.23 233.52 4340.83 4274.33 -450.06 -564.46 5959583.51 675669.33 GYD-CT-CMS Halliburton Company Survey Report Company: BP Amoco Field: Prudhoe Bay Site: PB DS 15 Well: 15-02 Wellpath: 15-02BP81 Survc~ - Date: 6/27/2006 Time: 16:19:51 Page: 3 Co-ordinate(1~E) Reference: Well: 15-02, True North Vertical ('TVD) Reference: 15-02B: 66.5 Section (VS) Reference: Well (O.OON,O.OOE,242.52Azi) ~ Survey Calculation Method: Minimum Curvature Db: Oracle --- ~MD Incl Azim TVD - 5ysTVD - Yi3 E/VV _ MapN - MapE "Tool ft deg deg ft ft ft ft ft ft 4578.50 45.27 233.64 4358.43 4291.93 -460.60 -578.75 5959572.63 675655.30 GYD-CT-CMS 4603.50 45.47 233.80 4376.00 4309.50 -471.13 -593.09 5959561.77 675641.21 GYD-CT-CMS 4628.50 45.33 233.77 4393.55 4327.05 -481.65 -607.45 5959550.92 675627.10 GYD-CT-CMS 4653.50 45.45 233.82 4411.11 4344.61 -492.16 -621.81 5959540.08 675612.99 GYD-CT-CMS 4678.50 45.70 233.85 4428.61 4362.11 -502.70 -636.23 5959529.21 675598.83 GYD-CT-CMS 4703.50 45.67 233.84 4446.07 4379.57 -513.25 -650.67 5959518.32 675584.63 GYD-CT-CMS 4728.50 45.71 233.75 4463.53 4397.03 -523.82 -665.10 5959507.42 675570.45 GYD-CT-CMS 4753.50 45.83 233.78 4480.97 4414.47 -534.40 -679.55 5959496.49 675556.26 GYD-CT-CMS 4778.50 45.76 233.84 4498.40 4431.90 -544.99 -694.02 5959485.58 675542.05 GYD-CT-CMS 4803.50 45.73 233.76 4515.85 4449.35 -555.56 -708.47 5959474.67 675527.85 GYD-CT-CMS 4828.50 45.69 233.87 4533.31 4466.81 -566.13 -722.91 5959463.77 675513.66 GYD-CT-CMS 4853.50 45.85 233.77 4550.75 4484.25 -576.70 -737.37 5959452.86 675499.45 GYD-CT-CMS 4878.50 45.10 233.69 4568.28 4501.78 -587.25 -751.74 5959441.98 675485.33 GYD-CT-CMS 4903.50 45.25 233.80 4585.90 4519.40 -597.73 -766.04 5959431.16 675471.29 GYD-CT-CMS 4928.50 45.43 233.75 4603.47 4536.97 -608.24 -780.38 5959420.32 675457.19 GYD-CT-CMS 4953.50 45.58 233.77 4620.99 4554.49 -618.78 -794.77 5959409.44 675443.06 GYD-CT-CMS 4978.50 45.27 233.93 4638.54 4572.04 -629.29 -809.15 5959398.60 675428.93 GYD-CT-CMS 5003.50 45.29 234.00 4656.13 4589.63 -639.74 -823.51 5959387.82 675414.82 GYD-CT-CMS 5028.50 45.44 234.05 4673.70 4607.20 -650.19 -837.91 5959377.04 675400.67 GYD-CT-CMS 5053.50 45.31 234.19 4691.26 4624.76 -660.62 -852.32 5959366.27 675386.50 GYD-CT-CMS 5078.50 45.17 234.27 4708.86 4642.36 -670.99 -866.73 5959355.56 675372.35 GYD-CT-CMS 5103.50 45.27 234.41 4726.47 4659.97 -681.34 -881.15 5959344.88 675358.18 GYD-CT-CMS 5128.50 45.37 234.45 4744.05 4677.55 -691.68 -895.60 5959334.21 675343.97 GYD-CT-CMS 5153.50 45.49 234.61 4761.59 4695.09 -702.01 -910.11 5959323.54 675329.71 GYD-CT-CMS 5178.50 45.47 234.84 4779.12 4712.62 -712.31 -924.66 5959312.91 675315.40 GYD-CT-CMS 5203.50 45.47 235.08 4796.65 4730.15 -722.54 -939.25 5959302.33 675301.06 GYD-CT-CMS 5228.50 45.57 235.17 4814.17 4747.67 -732.74 -953.89 5959291.80 675286.67 GYD-CT-CMS 5253.50 45.47 235.30 4831.69 4765.19 -742.91 -968.54 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5041.94 4975.44 -862.36 -1146.07 5959157.71 675097.59 GYD-CT-CMS 5578.50 46.20 237.42 5059.28 4992.78 -872.08 -1161.24 5959147.64 675082.65 GYD-CT-CMS 5603.50 46.40 237.57 5076.55 5010.05 -881.79 -1176.48 5959137.58 675067.64 GYD-CT-CMS 5628.50 46.39 237.60 5093.79 5027.29 -891.49 -1191.76 5959127.52 675052.59 GYD-CT-CMS 5653.50 46.59 237.64 5111.01 5044.51 -901.20 -1207.08 5959117.45 675037.51 GYD-CT-CMS 5678.50 46.16 237.78 5128.25 5061.75 -910.87 -1222.38 5959107.43 675022.45 GYD-CT-CMS 5703.50 46.11 237.90 5145.58 5079.08 -920.46 -1237.63 5959097.48 675007.42 GYD-CT-CMS 5728.50 46.41 237.96 5162.86 5096.36 -930.05 -1252.94 5959087.53 674992.34 GYD-CT-CMS 5753.50 46.52 238.12 5180.08 5113.58 -939.65 -1268.32 5959077.58 674977.20 GYD-CT-CMS 5778.50 46.77 238.30 5197.24 5130.74 -949.22 -1283.77 5959067.65 674961.97 GYD-CT-CMS 5803.50 47.12 238.38 5214.31 5147.81 -958.81 -1299.32 5959057.70 674946.66 GYD-CT-CMS 5828.50 47.23 238.51 5231.31 5164.81 -968.41 -1314.94 5959047.74 674931.26 GYD-CT-CMS 5853.50 47.47 238.52 5248.24 5181.74 -978.01 -1330.62 5959037.77 674915.81 GYD-CT-CMS 5878.50 47.72 238.60 5265.10 5198.60 -987.64 -1346.37 5959027.78 674900.29 GYD-CT-CMS Halliburton Com an P Y Survey Report Company: BP Amoco Field: Prudhoe Bay Site: PB DS 15 ~~ Well: 15-02 Wellpath: 15-02BPB1 Survev Date: 6/27/2006 Time: 16:19:51 Page: 4 Co-ordinate(;~E) Reference: WeII: 15-02, True North Vertical (TVD) Reference: 15-02B: 66.5 Section (VS) Reference: Well (O.OON,O.OOE,24252Azi) Survey Calculation Method: Minimum Curvature Db: Oracle M1ID Incl Azim TVD Sys "fVD lY/S E!W MapN MapE Tool ft deg deg ft ft ft ft ft ft 5903.50 47.53 238.56 5281.95 5215.45 -997.27 -1362.13 5959017.78 674884.76 GYD-CT-CMS 5928.50 47.63 238.64 5298.82 5232.32 -1006.88 -1377.88 5959007.80 674869.24 GYD-CT-CMS 5953.50 47.70 238.65 5315.65 5249.15 -1016.50 -1393.67 5958997.82 674853.69 GYD-CT-CMS 5978.50 47.92 238.77 5332.44 5265.94 -1026.12 -1409.49 5958987.83 674838.09 GYD-CT-CMS 6003.50 48.26 238.89 5349.14 5282.64 -1035.75 -1425.41 5958977.83 674822.40 GYD-CT-CMS 6028.50 48.21 239.14 5365.79 5299.29 -1045.35 -1441.40 5958967.86 674806.65 GYD-CT-CMS 6053.50 48.30 239.32 5382.44 5315.94 -1054.89 -1457.43 5958957.95 674790.85 GYD-CT-CMS 6078.50 48.69 239.38 5399.01 5332.51 -1064.44 -1473.53 5958948.03 674774.97 GYD-CT-CMS 6103.50 48.84 239.46 5415.49 5348.99 -1074.00 -1489.72 5958938.09 674759.02 GYD-CT-CMS 6128.50 48.84 239.75 5431.94 5365.44 -1083.52 -1505.95 5958928.19 674743.01 GYD-CT-CMS 6153.50 49.05 239.89 5448.36 5381.86 -1093.00 -1522.25 5958918.33 674726.94 GYD-CT-CMS 6178.50 49.29 240.14 5464.70 5398.20 -1102.45 -1538.64 5958908.50 674710.78 GYD-CT-CMS 6203.50 49.36 240.29 5481.00 5414.50 -1111.87 -1555.09 5958898.69 674&94.5& GYD-CT-CMS 6228.50 49.30 240.52 5497.29 5430.79 -1121.24 -1571.58 5958888.95 674678.29 GYD-CT-CMS 6253.50 49.37 240.53 5513.58 5447.08 -1130.57 -1588.09 5958879.23 674662.01 GYD-CT-CMS 6278.50 49.71 240.63 5529.81 5463.31 -1139.91 -1604.66 5958869.50 674645.66 GYD-CT-CMS 6303.50 49.73 240.74 5545.97 5479.47 -1149.25 -1621.29 5958859.78 674629.26 GYD-CT-CMS 6328.50 50.16 240.80 5562.06 5495.56 -1158.59 -1637.99 5958850.05 674612.78 GYD-CT-CMS 6353.50 50.30 240.81 5578.05 5511.55 -1167.97 -1654.76 5958840.28 674596.24 GYD-CT-CMS 6378.50 50.07 . 240.96 5594.06 5527.56 -1177.31 -1671.54 5958830.55 674579.68 GYD-CT-CMS 6403.50 49.91 240.99 5610.13 5543.63 -1186.60 -1688.28 5958820.87 674563.16 GYD-CT-CMS 6428.50 49.91 241.06 5626.23 5559.73 -1195.87 -1705.01 5958811.21 674546.66 GYD-CT-CMS 6453.50 49.77 240.98 5642.35 5575.85 -1205.12 -1721.73 5958801.57 674530.16 GYD-CT-CMS 6478.50 49.59 241.11 5658.53 5592.03 -1214.35 -1738.40 5958791.95 674513.71 GYD-CT-CMS 6503.50 49.66 241.06 5674.72 5608.22 -1223.56 -1755.08 5958782.36 674497.26 GYD-CT-CMS 6528.50 49.30 241.15 5690.97 5624.47 -1232.74 -1771.71 5958772.79 674480.84 GYD-CT-CMS 6553.50 49.06 241.00 5707.31 5640.81 -1241.89 -1788.27 5958763.25 674464.50 GYD-CT-CMS 6578.50 48.95 240.98 5723.71 5657.21 -1251.04 -1804.77 5958753.72 674448.22 GYD-CT-CMS 6603.50 48.66 241.07 5740.17 5673.67 -1260.16 -1821.23 5958744,22 674431.98 GYD-CT-CMS 6628.50 48.45 241.18 5756.72 5690.22 -1269.21 -1837.64 5958734.79 674415.79 GYD-CT-CMS 6653.50 48.43 241.25 5773.31 5706.81 -1278.21 -1854.04 5958725.40 674399.61 GYD-CT-CMS 6678.50 48.10 241.17 5789.95 5723.45 -1287.20 -1870.39 5958716.04 674383.48 GYD-CT-CMS 6703.50 47.83 241.31 5806.69 5740.19 -1296.13 -1886.66 5958706.72 674367.42 GYD-CT-CMS 6728.50 47.91 241.36 5823.46 5756.96 -1305.03 -1902.93 5958697.45 674351.36 GYD-CT-CMS 6753.50 47.57 241.52 5840.27 5773.77 -1313.87 -1919.18 5958688.23 674335.32 GYD-CT-CMS 6778.50 47.51 241.62 5857.15 5790.65 -1322.65 -1935.40 5958679.07 674319.31 GYD-CT-CMS 6803.50 47.42 241.72 5874.05 5807.55 -1331.40 -1951.62 5958669.95 674303.31 GYD-CT-CMS 6828.50 47.13 241.75 5891.01 5824.51 -1340.09 -1967.79 5958660.88 674287.34 GYD-CT-CMS 6853.50 47.19 241.79 5908.01 5841.51 -1348.76 -1983.94 5958651.83 674271.40 GYD-CT-CMS 6878.50 47.46 241.73 5924.96 5858.46 -1357.46 -2000.14 5958642.76 674255.42 GYD-CT-CMS 6903.50 47.19 241.73 5941.90 5875.40 -1366.17 -2016.33 5958633.67 674239.44 GYD-CT-CMS 6928.50 47.09 241.80 5958.91 5892.41 -1374.83 -2032.47 5958624.63 674223.50 GYD-CT-CMS 6953.50 46.84 241.82 5975.97 5909.47 -1383.47 -2048.58 5958615.62 674207.61 GYD-CT-CMS 6978.50 46.91 241.74 5993.06 5926.56 -1392.10 -2064.65 5958606.62 674191.74 GYD-CT-CMS 7003.50 46.97 241.74 6010.13 5943.63 -1400.74 -2080.74 5958597.60 674175.86 GYD-CT-CMS 7028.50 46.79 241.80 6027.22 5960.72 -1409.38 -2096.82 5958588.59 674159.99 GYD-CT-CMS 7053.50 46.98 241.79 6044.30 5977.80 -1418.00 -2112.90 5958579.59 674144.11 GYD-CT-CMS 7078.50 46.78 241.70 6061.39 5994.89 -1426.64 -2128.98 5958570.58 674128.24 GYD-CT-CMS 7103.50 46.61 241.73 6078.54 6012.04 -1435.26 -2145.00 5958561.59 674112.43 GYD-CT-CMS 7128.50 46.35 241.68 6095.75 6029.25 -1443.85 -2160.96 5958552.62 674096.68 GYD-CT-CMS 7153.50 46.46 241.58 6112.99 6046.49 -1452.46 -2176.89 5958543.65 674080.95 GYD-CT-CMS 7178.50 46.90 241.54 6130.14 6063.64 -1461.12 -2192.88 5958534.61 674065.17 GYD-CT-CMS Halliburton Com an P Y Survey Report Company: BP Amoco Field: Prudhoe Bay ~' Site: PB DS 15 i Well: 15-02 Wellpath: 15-02BP61 Survey --_ _ _ _ Date: 6/27/2006 Time: 16:19:51 Page: Co-ordinate(NE) Reference: Well: 15-02, True North Vertical (TVD) Reference: 15-028: 66.5 Section (VS) Reference: Well (O.OON,O.OOE,242.52Azi) Survey Calculation Method: Minimum Curvature Db: 5 rade MD lncl Azim TVD Sys "l'VD N/S E/V1' MapN MapE "fool ft deg deg ft ft ft ft ft ft 7203.50 46.78 241.53 6147.24 6080.74 -1469.81 -2208.92 5958525.55 674049.35 GYD-CT-CMS 7228.50 46.54 241.53 6164.40 6097.90 -1478.48 -2224.90 5958516.51 674033.57 GYD-CT-CMS 7253.50 46.38 241.54 6181.62 6115.12 -1487.11 -2240.83 5958507.50 674017.85 GYD-CT-CMS 7278.50 46.46 241.60 6198.86 6132.36 -1495.74 -2256.76 5958498.51 674002.13 GYD-CT-CMS 7303.50 46.20 241.58 6216.12 6149.62 -1504.34 -2272.66 5958489.54 673986.43 GYD-CT-CMS 7328.50 45.88 241.53 6233.47 6166.97 -1512.91 -2288.49 5958480.60 673970.81 GYD-CT-CMS 7353.50 46.03 241.51 6250.85 6184.35 -1521.48 -2304.28 5958471.66 673955.22 GYD-CT-CMS 7378.50 45.95 241.41 6268.22 6201.72 -1530.07 -2320.08 5958462.70 673939.64 GYD-CT-CMS 7403.50 45.85 241.42 6285.62 6219.12 -1538.66 -2335.84 5958453.74 673924.08 GYD-CT-CMS 7428.50 45.83 241.47 6303.04 6236.54 -1547.23 -2351.59 5958444.81 673908.53 GYD-CT-CMS 7453.50 45.49 241.42 6320.51 6254.01 -1555.78 -2367.30 5958435.89 673893.03 GYD-CT-CMS 7478.50 45.46 241.35 6338.04 6271.54 -1564.32 -2382.95 5958426.99 673877.59 GYD-CT-CMS 7503.50 45.25 241.34 6355.61 6289.11 -1572.85 -2398.55 5958418.10 673862.19 GYD-CT-CMS 7528.50 45.00 241.23 6373.25 6306.75 -1581.36 -2414.09 5958409.23 673846.85 GYD-CT-CMS 7553.50 44.77 241.20 6390.96 6324.46 -1589.85 -2429.55 5958400.37 673831.60 GYD-CT-CMS 7578.50 44.66 241.24 6408.73 6342.23 -1598.32 -2444.97 5958391.55 673816.38 GYD-CT-CMS 7603.50 44.40 241.19 6426.55 6360.05 -1606.76 -2460.34 5958382.75 673801.22 GYD-CT-CMS 7628.50 44.25 241.13 6444.43 6377.93 -1615.19 -2475.64 5958373.96 673786.12 GYD-CT-CMS 7653:50 44.12 241.19 6462.36 6395.86 -1623.59 -2490.90 5958365.20 673771.06 GYD-CT-CMS 7678.50 43.75 241.16 6480.36 6413.86 -1631.96 -2506.10 5958356.49 673756.07 GYD-CT-CMS 7703.50 43.64 241.14 6498.44 6431.94 -1640.29 -2521.23 5958347.80 673741.14 GYD-CT-CMS 7728.50 43.53 241.11 6516.55 6450.05 -1648.61 -2536.32 5958339.13 673726.25 GYD-CT-CMS 7753.50 43.32 241.13 6534.71 6468.21 -1656.91 -2551.37 5958330.48 673711.40 GYD-CT-CMS 7778.50 43.22 241.18 6552.91 6486.41 -1665.18 -2566.38 5958321.86 673696.59 GYD-CT-CMS 7803.50 42.94 241.07 6571.17 6504.67 -1673.43 -2581.33 5958313.27 673681.83 GYD-CT-CMS 7828.50 42.64 241.21 6589.52 6523.02 -1681.62 -2596.20 5958304.73 673667.16 GYD-CT-CMS 7853.50 42.53 241.18 6607.92 6541.42 -1689.78 -2611.03 5958296.23 673652.53 GYD-CT-CMS 7878.50 42.20 241.18 6626.39 6559.89 -1697.90 -2625.79 5958287.77 673637.97 GYD-CT-CMS 7903.50 42.12 241.30 6644.93 6578.43 -1705.97 -2640.50 5958279.35 673623.45 GYD-CT-CMS 7928.50 41.82 241.46 6663.51 6597.01 -1713.98 -2655.17 5958271.00 673608.97 GYD-CT-CMS 7953.50 41.15 241.32 6682.24 6615.74 -1721.91 -2669.71 5958262.73 673594.62 GYD-CT-CMS 7978.50 41.09 241.36 6701.07 6634.57 -1729.79 -2684.14 5958254.51 673580.38 GYD-CT-CMS 8003.50 40.99 241.33 6719.93 6653.43 -1737.66 -2698.54 5958246.31 673566.17 GYD-CT-CMS 8028.50 40.70 241.36 6738.84 6672.34 -1745.51 -2712.89 5958238.13 673552.01 GYD-CT-CMS 8053.50 40.47 241.35 6757.83 6691.33 -1753.30 -2727.16 5958230.00 673537.92 GYD-CT-CMS 8078.50 40.24 241.38 6776.88 6710.38 -1761.06 -2741.37 5958221.91 673523.90 GYD-CT-CMS 8103.50 39.94 241.52 6796.01 6729.51 -1768.75 -2755.51 5958213.89 673509.94 GYD-CT-CMS 8128.50 39.80 241.52 6815.19 6748.69 -1776.40 -2769.60 5958205.92 673496.04 GYD-CT-CMS 8153.50 39.54 241.41 6834.44 6767.94 -1784.02 -2783.62 5958197.97 673482.20 GYD-CT-CMS 8178.50 39.27 241.55 6853.75 6787.25 -1791.60 -2797.56 5958190.07 673468.44 GYD-CT-CMS 8203.50 39.18 241.33 6873.12 6806.62 -1799.16 -2811.45 5958182.19 673454.74 GYD-CT-CMS 8228.50 38.90 241.36 6892.54 6826.04 -1806.71 -2825.27 5958174.32 673441.10 GYD-CT-CMS 8253.50 38.62 241.44 6912.03 6845.53 -1814.20 -2839.01 5958166.50 673427.54 GYD-CT-CMS 8278.50 38.61 241.34 6931.57 6865.07 -1821.67 -2852.71 5958158.71 673414.02 GYD-CT-CMS 8303.50 38.35 241.32 6951.14 6884.64 -1829.13 -2866.35 5958150.93 673400.55 GYD-CT-CMS 8328.50 38.00 241.31 6970.79 6904.29 -1836.55 -2879.91 5958143.20 673387.18 GYD-CT-CMS 8353.50 37.96 241.30 6990.50 6924.00 -1843.94 -2893.41 5958135.50 673373.86 GYD-CT-CMS 8378.50 37.53 241.27 7010.26 6943.76 -1851.29 -2906.83 5958127.84 673360.62 GYD-CT-CMS 8403.50 37.39 241.34 7030.11 6963.61 -1858.59 -2920.16 5958120.22 673347.45 GYD-CT-CMS 8428.50 37.31 241.24 7049.98 6983.48 -1865.88 -2933.47 5958112.63 673334.33 GYD-CT-CMS 8453.50 37.06 241.28 7069.90 7003.40 -1873.14 -2946.72 5958105.06 673321.25 GYD-CT-CMS 8478.50 37.22 241.18 7089.83 7023.33 -1880.41 -2959.95 5958097.48 673308.20 GYD-CT-CMS 8503.50 37.49 241.23 7109.70 7043.20 -1887.71 -2973.24 5958089.87 673295.08 GYD-CT-CMS Halliburton Com an P Y Survey Report Company: BP Amoco Date: 6/27/2006 Time• 16:19:51 Page: 6 Field Pru dhoe Bay Co-ordinate(NE) Referener. Well: 15-02, Tru e North Site: PB DS 15 Verti cal (TVD) Reference: 15-026: 66.5 Well: 15- 02 Section (VS) Reference: Well (O.OON,O.O OE,24252Azi) W'etlpath: 15-026P61 Survey Calculati on Method: Minimum Curvature Db: Oracle Survcv [b1D Incl Azim 'fVD Sys TVD -- - N/S _ _ E/W _- MapN - MapE Tool ft deg deg ft ft ft ft ft ft ~ 8528.50 37.58 241.21 7129.53 7063.03 -1895.05 -2986.59 5958082.22 673281.91 GYD-CT-CMS 8553.50 37.46 241.16 7149.35 7082.85 -1902.38 -2999.93 5958074.58 673268.74 GYD-CT-CMS 8578.50 37.39 241.23 7169.21 7102.71 -1909.70 -3013.24 5958066.95 673255.61 GYD-CT-CMS 8603.50 37.34 241.24 7189.08 7122.58 -1917.01 -3026.54 5958059.33 673242.48 GYD-CT-CMS 8628.50 37.27 241.16 7208.96 7142.46 -1924.30 -3039.82 5958051.73 673229.38 GYD-CT-CMS 8653.50 37.13 241.13 7228.88 7162.38 -1931.60 -3053.06 5958044.12 673216.32 GYD-CT-CMS 8678.50 37.15 241.17 7248.81 7182.31 -1938.88 -3066.28 5958036.53 673203.27 GYD-CT-CMS 8703.50 37.13 241.04 7268.73 7202.23 -1946.18 -3079.49 5958028.93 673190.23 GYD-CT-CMS 8728.50 36.98 241.05 7288.69 7222.19 -1953.47 -3092.68 5958021.33 673177.23 GYD-CT-CMS 8753.50 36.89 241.30 7308.67 7242.17 -1960.71 -3105.84 5958013.78 673164.24 GYD-CT-CMS 8778.50 36.79 241.41 7328.68 7262.18 -1967.90 -3118.99 5958006.29 673151.26 GYD-CT-CMS 8794.00 36.62 241.41 7341.10 7274.60 -1972.33 -3127.13 5958001.67 673143.23 MWD+IFR+MS 8871.84 34.96 237.30 7404.25 7337.75 -1995.49 -3166.29 5957977.60 673104.62 MWD+IFR+MS 8965.92 34.17 231.89 7481.74 7415.24 -2026.37 -3209.77 5957945.71 673061.88 MWD+IFR+MS 9060.61 31.77 225.96 7561.20 7494.70 -2060.12 -3248.63 5957911.06 673023.83 MWD+IFR+MS 9155.26 32.84 217.95 7641.23 7574.73 -2097.70 -3282.34 5957872.70 672991.01 MWD+IFR+MS 9249.97 34.55 212.78 7720.05 7653.55 -2140.54 -3312.68 5957829.17 672961.68 MWD+IFR+MS 9343.25 33.66 213.14 7797.28 7730.78 -2184.43 -3341.13 5957784.63 672934.27 MWD+IFR+MS 9438.39 34.97 212.98 7875.86 7809.36 -2229.38 -3370.39 5957739.01 672906.07 MWD+IFR+MS 9533.33 35.74 212.42 7953.29 7886.79 -2275.61 -3400.07 5957692.10 672877.49 MWD+-FR+MS 9627.76 35.02 211.57 8030.28 7963.78 -2321.97 -3429.04 5957645.07 672849.62 MWD+IFR+MS 9722.00 34.39 211.39 8107.76 8041.26 -2367.73 -3457.06 5957598.67 672822.68 MWD+IFR+MS 9816.69 33.85 216.20 8186.16 8119.66 -2411.85 -3486.57 5957553.87 672794.22 MWD+IFR+MS 9911.30 33.35 216.59 8264.97 8198.47 -2453.99 -3517.63 5957511.01 672764.15 MWD+IFR+MS 9959.72 32.88 217.10 8305.52 8239.02 -2475.16 -3533.49 5957489.48 672748.79 MWD+IFR+MS 10007.01 33.13 221.43 8345.19 8278.69 -2495.09 -3549.79 5957469.17 672732.97 MWD+IFR+MS 10035.59 30.77 224.20 8369.44 8302.94 -2506.19 -3560.06 5957457.84 672722.96 MWD+IFR+MS 10067.14 29.53 236.38 8396.74 8330.24 -2516.29 -3572.17 5957447.46 672711.09 MWD+IFR+MS 10097.71 26.78 246.67 8423.71 8357.21 -2523.20 -3584.78 5957440.26 672698.65 MWD+IFR+MS 10129.76 24.14 257.47 8452.66 8386.16 -2527.48 -3597.81 5957435.67 672685.72 MWD+IFR+MS 10161.59 23.71 257.78 8481.75 8415.25 -2530.25 -3610.42 5957432.61 672673.18 MWD+IFR+MS 10193.78 24.35 260.05 8511.16 8444.66 -2532.77 -3623.28 5957429.79 672660.38 MWD+IFR+MS 10225.47 27.79 265.01 8539.62 8473.12 -2534.54 -3637.08 5957427.70 672646.63 MWD+IFR+MS 10257.00 29.27 273.66 8567.33 8500.83 -2534.69 -3652.11 5957427.20 672631.61 MWD+IFR+MS 10288.72 28.45 282.85 8595.13 8528.63 -2532.51 -3667.22 5957429.02 672616.45 MWD+IFR+MS 10319.93 29.41 294.32 8622.46 8555.96 -2527.70 -3681.46 5957433.50 672602.10 MWD+IFR+MS 10351.56 30.11 298.66 8649.92 8583.42 -2520.69 -3695.50 5957440.17 672587.90 MWD+IFR+MS 10380.91 29.40 298.41 8675.40 8608.90 -2513.73 -3708.30 5957446.83 672574.95 MWD+IFR+MS 10412.41 30.19 306.58 8702.75 8636.25 -2505.33 -3721.46 5957454.92 672561.59 MWD+IFR+MS 10444.31 29.83 306.63 8730.38 8663.88 -2495.82 -3734.27 5957464.13 672548.56 MWD+IFR+MS 10475.62 31.77 308.80 8757.27 8690.77 -2486.00 -3746.95 5957473.64 672535.66 MWD+IFR+MS 10507.50 35.23 313.21 8783.85 8717.35 -2474.44 -3760.19 5957484.88 672522.15 MWD+IFR+MS 10538.26 39.35 317.45 8808.32 8741.82 -2461.18 -3773.26 5957497.84 672508.77 MWD+IFR+MS 10569.54 43.58 321.13 8831.76 8765.26 -2445.47 -3786.74 5957513.23 672494.93 MWD+IFR+MS 10602.27 47.62 323.34 8854.66 8788.16 -2426.98 -3801.05 5957531.38 672480.20 MWD+IFR+MS 10632.40 50.74 325.37 8874.35 8807.85 -2408.45 -3814.33 5957549.59 672466.49 MWD+IFR+MS 10664.32 54.55 327.01 8893.72 8827.22 -2387.37 -3828.43 5957570.33 672451.89 MWD+IFR+MS 10696.55 57.87 328.67 8911.64 8845.14 -2364.69 -3842.68 5957592.67 672437.12 MWD+IFR+MS 10727.90 61.54 329.48 8927.45 8860.95 -2341.47 -3856.59 5957615.55 672422.67 MWD+IFR+MS 10759.67 65.79 329.75 8941.54 8875.04 -2316.92 -3870.98 5957639.76 672407.70 MWD+IFR+MS 10790.96 68.66 328.43 8953.66 8887.16 -2292.17 -3885.81 5957664.15 672392.31 MWD+IFR+MS 10821.09 72.32 328.48 8963.72 8897.22 -2267.97 -3900.66 5957688.00 672376.89 MWD+IFR+MS Halliburton Com an p Y Survey Report ~~ Company: BP Amoco -- --_ - - Date: 6!27/2006 Time: 16:19:51 Page: 7 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 15-02, True North Site: PB DS 15 Vertical ('TVD) Reference: 15-02B: 66.5 Welt: 15-02 Section (VS) Reference: WeII (O.OON,OAOE,242.52Azi) Wcllpath: 15-026P81 Survey Calwla6on Method: Minimum Curvature Db: Orade Surveti MD lncl Azim 'CVD Sys'1'VD N/S E/W MapN ___. MapE Tool ft deg deg ft ft ft ft ft ft 10852.53 76.23 330 25 8972.24 8905.74 -2241.93 -3916.07 5957713.66 672360.87 MWD+IFR+MS 10883.45 79.95 333.17 8978.62 8912.12 -2215.30 -3930.40 5957739.95 672345.92 MWD+IFR+MS 10916.53 82.00 333.65 8983.81 8917.31 -2186.08 -3945.03 5957768.81 672330.62 MWD+IFR+MS 10947.56 85.43 336.38 8987.20 8920.70 -2158.13 -3958.05 5957796.45 672316.95 MWD+IFR+MS 10980.21 85.43 337.09 8989.80 8923.30 -2128.23 -3970.90 5957826.04 672303.39 MWD+IFR+MS 11036.00 85.43 337.09 8994.25 8927.75 -2077.01 -3992.55 5957876.74 672280.55 BLIND Halliburton Com any P Survey Report Company: BP Amoco Date: 6/27/2006 'Time: 16:21:16 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: WeII: 15-02, True North Site: PB DS 15 Vertical (TVll) Reference: 15-028: 66.5 Well: 15-02 ~ Wellpath: 15-02BPB2 i_ _. ___ - _ _ _ - __ _ - - - Section (VS) Reference: Well (O.OON,O.OOE,242.10Azi) Survey Calcularion Method: Minimum Curvature Db: Oracle - ---- - - -- - -- Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 33.60 0.00 0.00 33.60 -32.90 0.00 0.00 5960046.65 676223.05 TIE LINE 103.50 0.19 123.37 103.50 37.00 -0.06 0.10 5960046.59 676223.15 GYD-CT-CMS 203.50 0.37 241.38 203.50 137.00 -0.31 -0.05 5960046.34 676223.01 GYD-CT-CMS 303.50 0.43 229.99 303.50 237.00 -0.71 -0.62 5960045.93 676222.45 GYD-CT-CMS 403.50 0.48 217.50 403.49 336.99 -1.28 -1.16 5960045.34 676221.92 GYD-CT-CMS 503.50 0.41 178.21 503.49 436.99 -1.97 -1.41 5960044.65 676221.69 GYD-CT-CMS 603.50 0.35 140.11 603.49 536.99 -2.56 -1.20 5960044.06 676221.91 GYD-CT-CMS 703.50 0.38 136.60 703.49 636.99 -3.04 -0.77 5960043.60 676222.35 GYD-CT-CMS 803.50 0.41 133.72 803.48 736.98 -3.52 -0.29 5960043.12 676222.84 GYD-CT-CMS 903.50 0.40 146.67 903.48 836.98 -4.06 0.16 5960042.59 676223.31 GYD-CT-CMS 1003.50 0.38 157.47 1003.48 936.98 -4.66 0.48 5960042.00 676223.64 GYD-CT-CMS 1103.50 0.42 112.00 1103.48 1036.98 -5.10 0.95 5960041.57 676224.12 GYD-CT-CMS 1203.50 0.47 68.24 1203.47 1136.97 -5.09 1.67 5960041.60 676224.84 GYD-CT-CMS 1303.50 0.61 68.71 1303.47 1236.97 -4.74 2.55 5960041.97 676225.71 GYD-CT-CMS 1403.50 0.75 68.22 1403.46 1336.96 -4.31 3.65 5960042.43 676226.80 GYD-CT-CMS 1503.50 0.71 42.16 1503.46 1436.96 -3.61 4.67 5960043.15 676227.81 GYD-CT-CMS 1603.50 0.67 16.47 1603.45 1536.95 -2.59 5.25 5960044.19 676228.36 GYD-CT-CMS 1703.50 0.55 0.45 1703.44 1636.94 -1.55 5.42 5960045.23 676228.51 GYD-CT-CMS 1803.50 0.43 345.86 1803.44 1736.94 -0.70 5.34 5960046.07 676228.40 GYD-CT-CMS 1903.50 0.37 9.45 1903.44 1836.94 -0.02 5.30 5960046.75 676228.35 GYD-CT-CMS 2003.50 0.30 41.67 2003.43 1936.93 0.49 5.52 5960047.27 676228.56 GYD-CT-CMS 2103.50 0.20 298.85 2103.43 2036.93 0.77 5.55 5960047.55 676228.58 GYD-CT-CMS 2203.50 0.25 59.69 2203.43 2136.93 0.97 5.58 5960047.75 676228.61 GYD-CT-CMS 2303.50 0.27 107.37 2303.43 2236.93 1.01 5.99 5960047.80 676229.02 GYD-CT-CMS 2403.50 0.28 189.63 2403.43 2336.93 0.70 6.18 5960047.49 676229.21 GYD-CT-CMS 2503.50 0.49 193.57 2503.43 2436.93 0.04 6.04 5960046.83 676229.08 GYD-CT-CMS 2603.50 0.55 182.02 2603.43 2536.93 -0.86 5.92 5960045.93 676228.99 GYD-CT-CMS 2703.50 0.86 171.14 2703.42 2636.92 -2.08 6.02 5960044.72 676229.12 GYD-CT-CMS Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model : bggm2005 Well: 15-02 Slot Name: 02 15-02 WeII Position: +N/-S 1210.77 ft Northing: 5960046.65 ft Latitude: 70 17 47.144 N +E/-W -45.55 ft Easting : 676223.05 ft Longitude: 148 34 22.541 W Position Uncertainty: 0.00 ft Wellpath: 15-02BPB2 Drilled From: 15-026PB1 50029206970272 Tie-on Depth: 10602.27 ft Current Datum: 15-026: Height 66.50 ft Above System Datum: Mean Sea Level Magnetic Data: 6/5/2006 Declination: 24.57 deg Field Strength: 57611 nT Mag Dip Angle: 80.91 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 33.60 0.00 0.00 242.10 Survey Program for Definitive Wellpath Date: 6/27/2006 Validated: Yes Version: 22 Actual From To Survey Toolcode Tool Name ft ft 103.50 8778.50 15-02_Gyrodata (103.50-9039.60 GYD-CT-CMS Gyrodata cont.casing m/s 8794.00 10602.27 15-026P61 IIFR+MS+SAG (8794.00 MWD+IFR+MS MWD +IFR + Multi Station' 10632.00 11036.70 15-026P62 IIFR+MS+SAG (10632.0 MWD+IFR+MS MWD +IFR + Multi Station ' ~ Halliburton Com an P Y Survey Report Company: BP Amoco Field: Prudhoe Bay Site: PB DS 15 Wcll: 15-02 ~Yellpath: 15-026P62 ,_ __ -- - Sure ev MD Incl ', ft deg _ -- Azim deg -- TVD ft _ - - Sys TVD ft Date: 6/27/2006 Time: 16:21:16 Page: Z Co-ordinate(NE) Reference. Well: 15-02, True North Vertical (TVD) Reference: 15-02B: 66.5 Section (VS) Reference: Well (O.OON,O.OOE,242.10Azi) Survey Calculation Method: Minimum Curvature Db: Oracle -- _- - - -- -- _ . _ _I NlS E/~'V Map[V MapE Tool ft ft ft ft 2803.50 1.78 204.95 2803.39 2736.89 -4.23 5.48 5960042.55 676228.63 GYD-CT-CMS 2903.50 4.41 226.52 2903.24 2836.74 -8.28 2.03 5960038.42 676225.28 GYD-CT-CMS 3003.50 6.54 230.19 3002.78 2936.28 -14.57 -5.13 5960031.96 676218.26 GYD-CT-CMS 3103.50 8.69 230.35 3101.89 3035.39 -23.04 -15.32 5960023.26 676208.27 GYD-CT-CMS 3203.50 12.62 229.05 3200.15 3133.65 -35.03 -29.40 5960010.95 676194.48 GYD-CT-CMS 3303.50 15.13 228.69 3297.22 3230.72 -50.80 -47.45 5959994.75 676176.80 GYD-CT-CMS 3403.50 17.67 230.01 3393.15 3326.65 -69.17 -68.89 5959975.88 676155.81 GYD-CT-CMS 3428.50 18.18 229.49 3416.93 3350.43 -74.15 -74.76 5959970.78 676150.05 GYD-CT-CMS 3453.50 18.80 229.69 3440.64 3374.14 -79.29 -80.80 5959965.50 676144.14 GYD-CT-CMS 3478.50 19.26 230.08 3464.28 3397.78 -84.54 -87.03 5959960.10 676138.03 GYD-CT-CMS 3503.50 19.77 230.21 3487.84 3421.34 -89.89 -93.44 5959954.60 676131.75 GYD-CT-CMS 3528.50 20.39 230.30 3511.32 3444.82 -95.38 -100.04 5959948.96 676125.28 GYD-CT-CMS 3553.50 21.04 230.50 3534.70 3468.20 -101.01 -106.86 5959943.17 676118.60 GYD-CT-CMS 3578.50 22.03 230.78 3557.96 3491.46 -106.83 -113.95 5959937.18 676111.64 GYD-CT-CMS 3603.50 22.88 230.98 3581.06 3514.56 -112.86 -121.36 5959930.99 676104.38 GYD-CT-CMS 3628.50 23.51 231.13 3604.04 3537.54 -119.05 -129.02 5959924.62 676096.87 GYD-CT-CMS 3653.50 24.15 231.39 3626.91 3560.41 -125.37 -136.90 5959918.12 676089.14 GYD-CT-CMS 3678.50 24.87 231.59 3649.66 3583.16 -131.82 -145.01 5959911.47 676081.18 GYD-CT-CMS 3703.50 25.55 231.90 3672.28 3605.78 -138.42 -153.37 5959904.68 676072.97 GYD-CT-CMS 3728.50 26.06 231.82 3694.78 3628.28 -145.14 -161.93 5959897.76 676064.57 GYD-CT-CMS 3753.50 26.67 232.07 3717.18 3650.68 -151.98 -170.68 5959890.72 676056.00 GYD-CT-CMS 3778.50 27.34 232.13 3739.46 3672.96 -158.95 -179.63 5959883.54 676047.20 GYD-CT-CMS 3803.50 28.27 232.22 3761.57 3695.07 -166.11 -188.84 5959876.17 676038.16 GYD-CT-CMS 3828.50 28.94 232.33 3783.52 3717.02 -173.43 -198.31 5959868.63 676028.87 GYD-CT-CMS 3853.50 29.79 232.32 3805.30 3738.80 -180.92 -208.01 5959860.91 676019.35 GYD-CT-CMS 3878.50 30.82 232.38 3826.89 3760.39 -188.63 -218.00 5959852.98 676009.54 GYD-CT-CMS 3903.50 31.36 232.44 3848.30 3781.80 -196.50 -228.23 5959844.86 675999.50 GYD-CT-CMS 3928.50 32.12 232.37 3869.56 3803.06 -204.53 -238.65 5959836.60 675989.27 GYD-CT-CMS 3953.50 33.14 232.34 3890.61 3824.11 -212.76 -249.33 5959828.12 675978.80 GYD-CT-CMS 3978.50 33.83 232.33 3911.46 3844.96 -221.19 -260.24 5959819.44 675968.08 GYD-CT-CMS 4003.50 34.87 232.45 3932.10 3865.60 -229.80 -271.42 5959810.57 675957.11 GYD-CT-CMS 4028.50 35.73 232.39 3952.51 3886.01 -238.61 -282.87 5959801.49 675945.87 GYD-CT-CMS 4053.50 36.39 232.45 3972.72 3906.22 -247.58 -294.53 5959792.25 675934.42 GYD-CT-CMS 4078.50 37.19 232.46 3992.74 3926.24 -256.70 -306.40 5959782.85 675922.77 GYD-CT-CMS 4103.50 37.83 232.49 4012.57 3946.07 -265.98 -318.47 5959773.30 675910.92 GYD-CT-CMS 4128.50 38.49 232.54 4032.22 3965.72 -275.38 -330.73 5959763.61 675898.89 GYD-CT-CMS 4153.50 39.02 232.58 4051.72 3985.22 -284.89 -343.16 5959753.81 675886.69 GYD-CT-CMS 4178.50 40.03 232.78 4071.00 4004.50 -294.54 -355.81 5959743.87 675874.27 GYD-CT-CMS 4203.50 40.72 232.87 4090.05 4023.55 -304.32 -368.71 5959733.79 675861.60 GYD-CT-CMS 4228.50 41.72 233.13 4108.85 4042.35 -314.24 -381.87 5959723.57 675848.68 GYD-CT-CMS 4253.50 42.70 233.23 4127.37 4060.87 -324.30 -395.31 5959713.19 675835.47 GYD-CT-CMS 4278.50 43.82 233.33 4145.58 4079.08 -334.54 -409.05 5959702.63 675821.98 GYD-CT-CMS 4303.50 44.27 233.36 4163.55 4097.05 -344.92 -422.99 5959691.93 675808.29 GYD-CT-CMS 4328.50 44.51 233.30 4181.41 4114.91 -355.36 -437.02 5959681.16 675794.51 GYD-CT-CMS 4353.50 44.65 233.36 4199.22 4132.72 -365.84 -451.09 5959670.35 675780.69 GYD-CT-CMS 4378.50 44.61 233.42 4217.01 4150.51 -376.32 -465.19 5959659.55 675766.84 GYD-CT-CMS 4403.50 44.60 233.46 4234.81 4168.31 -386.78 -479.29 5959648.77 675752.99 GYD-CT-CMS 4428.50 44.76 233.35 4252.58 4186.08 -397.26 -493.41 5959637.96 675739.13 GYD-CT-CMS 4453.50 44.92 233.38 4270.31 4203.81 -407.77 -507.55 5959627.11 675725.23 GYD-CT-CMS 4478.50 45.13 233.33 4287.98 4221.48 -418.33 -521.74 5959616.23 675711.29 GYD-CT-CMS 4503.50 45.17 233.32 4305.61 4239.11 -428.92 -535.96 5959605.31 675697.33 GYD-CT-CMS 4528.50 45.24 233.44 4323.23 4256.73 -439.50 -550.20 5959594.40 675683.35 GYD-CT-CMS Halliburton Company Survey Report I Company: BP Amoco ~~ Ficld: Prudhoe Bay Site: PB DS 15 Wcll: 15-02 Wellpath: 15-02BPB2 Survc~ MD Inc! ft deg zim deg VD ft ys TVD ft Date: 6/27!2006 Time: 16:21:16 Page: 3 Co-ordinate(NE) Reference: Well: 15-02, True North Vertical (TVD) Reference: 15-02B: 66.5 Section (VS) Reference: Well (O.OON,O.OOE,242.10Azi) Survey Calculation Method: Minimum Curvature Db: Oracle N/S E/W MapN MapE Tool ft ft ft ft 4553.50 45.23 233.52 4340.83 4274.33 -450.06 -564.46 5959583.51 675669.33 GYD-CT-CMS 4578.50 45.27 233.64 4358.43 4291.93 -460.60 -578.75 5959572.63 675655.30 GYD-CT-CMS 4603.50 45.47 233.80 4376.00 4309.50 -471.13 -593.09 5959561.77 675641.21 GYD-CT-CMS 4628.50 45.33 233.77 4393.55 4327.05 -481.65 -607.45 5959550.92 675627.10 GYD-CT-CMS 4653.50 45.45 233.82 4411.11 4344.61 -492.16 -621.81 5959540.08 675612.99 GYD-CT-CMS 4678.50 45.70 233.85 4428.61 4362.11 -502.70 -636.23 5959529.21 675598.83 GYD-CT-CMS 4703.50 45.67 233.84 4446.07 4379.57 -513.25 -650.67 5959518.32 675584.63 GYD-CT-CMS 4728.50 45.71 233.75 4463.53 4397.03 -523.82 -665.10 5959507.42 675570.45 GYD-CT-CMS 4753.50 45.83 233.78 4480.97 4414.47 -534.40 -679.55 5959496.49 675556.26 GYD-CT-CMS 4778.50 45.76 233.84 4498.40 4431.90 -544.99 -694.02 5959485.58 675542.05 GYD-CT-CMS 4803.50 45.73 233.76 4515.85 4449.35 -555.56 -708.47 5959474.67 675527.85 GYD-CT-CMS 4828.50 45.69 233.87 4533.31 4466.81 -566.13 -722.91 5959463.77 675513.66 GYD-CT-CMS 4853.50 45.85 233.77 4550.75 4484.25 -576.70 -737.37 5959452.86 675499.45 GYD-CT-CMS 4878.50 45.10 233.69 4568.28 4501.78 -587.25 -751.74 5959441.98 675485.33 GYD-CT-CMS 4903.50 45.25 233.80 4585.90 4519.40 -597.73 -766.04 5959431.16 675471.29 GYD-CT-CMS 4928.50 45.43 233.75 4603.47 4536.97 -608.24 -780.38 5959420.32 675457.19 GYD-CT-CMS 4953.50 45.58 233.77 4620.99 4554.49 -618.78 -794.77 5959409.44 675443.06 GYD-CT-CMS 4978.50 45.27 233.93 4638.54 4572.04 -629.29 -809.15 5959398.60 675428.93 GYD-CT-CMS 5003.50 45.29 234.00 4656.13 4589.63 -639.74 -823.51 5959387.82 675414.82 GYD-CT-CMS 5028.50 45.44 234.05 4673.70 4607.20 -650.19 -837.91 5959377.04 675400.67 GYD-CT-CMS 5053.50 45.31 234.19 4691.26 4624.76 -660.62 -852.32 5959366.27 675386.50 GYD-CT-CMS 5078.50 45.17 234.27 4708.86 4642.36 -670.99 -866.73 5959355.56 675372.35 GYD-CT-CMS 5103.50 45.27 234.41 4726.47 4659.97 -681.34 -881.15 5959344.88 675358.18 GYD-CT-CMS 5128.50 45.37 234.45 4744.05 4677.55 -691.68 -895.60 5959334.21 675343.97 GYD-CT-CMS 5153.50 45.49 234.61 4761.59 4695.09 -702.01 -910.11 5959323.54 675329.71 GYD-CT-CMS 5178.50 45.47 234.84 4779.12 4712.62 -712.31 -924.66 5959312.91 675315.40 GYD-CT-CMS 5203.50 45.47 235.08 4796.65 4730.15 -722.54 -939.25 5959302.33 675301.06 GYD-CT-CMS 5228.50 45.57 235.17 4814.17 4747.67 -732.74 -953.89 5959291.80 675286.67 GYD-CT-CMS 5253.50 45.47 235.30 4831.69 4765.19 -742.91 -968.54 5959281.28 675272.26 GYD-CT-CMS 5278.50 45.50 235.41 4849.21 4782.71 -753.04 -983.21 5959270.81 675257.83 GYD-CT-CMS 5303.50 45.19 235.45 4866.79 4800.29 -763.13 -997.85 5959260.38 675243.43 GYD-CT-CMS 5328.50 45.33 235.46 4884.38 4817.88 -773.20 -1012.48 5959249.97 675229.05 GYD-CT-CMS 5353.50 45.21 235.65 4901.98 4835.48 -783.25 -1027.12 5959239.58 675214.64 GYD-CT-CMS 5378.50 45.28 235.77 4919.58 4853.08 -793.25 -1041.79 5959229.24 675200.21 GYD-CT-CMS 5403.50 45.16 236.08 4937.19 4870.69 -803.19 -1056.49 5959218.96 675185.75 GYD-CT-CMS 5428.50 45.46 236.12 4954.77 4888.27 -813.11 -1071.24 5959208.70 675171.24 GYD-CT-CMS 5453.50 45.73 236.22 4972.26 4905.76 -823.05 -1086.08 5959198.41 675156.64 GYD-CT-CMS 5478.50 45.72 236.47 4989.72 4923.22 -832.97 -1100.98 5959188.15 675141.98 GYD-CT-CMS 5503.50 45.82 236.79 5007.15 4940.65 -842.82 -1115.94 5959177.95 675127.25 GYD-CT-CMS 5528.50 45.91 237.01 5024.56 4958.06 -852.62 -1130.97 5959167.80 675112.46 GYD-CT-CMS 5553.50 46.00 237.33 5041.94 4975.44 -862.36 -1146.07 5959157.71 675097.59 GYD-CT-CMS 5578.50 46.20 237.42 5059.28 4992.78 -872.08 -1161.24 5959147.64 675082.65 GYD-CT-CMS 5603.50 46.40 237.57 5076.55 5010.05 -881.79 -1176.48 5959137.58 675067.64 GYD-CT-CMS 5628.50 46.39 237.60 5093.79 5027.29 -891.49 -1191.76 5959127.52 675052.59 GYD-CT-CMS 5653.50 46.59 237.64 5111.01 5044.51 -901.20 -1207.08 5959117.45 675037.51 GYD-CT-CMS 5678.50 46.16 237.78 5128.25 5061.75 -910.87 -1222.38 5959107.43 675022.45 GYD-CT-CMS 5703.50 46.11 237.90 5145.58 5079.08 -920.46 -1237.63 5959097.48 675007.42 GYD-CT-CMS 5728.50 46.41 237.96 5162.86 5096.36 -930.05 -1252.94 5959087.53 674992.34 GYD-CT-CMS 5753.50 46.52 238.12 5180.08 5113.58 -939.65 -1268.32 5959077.58 674977.20 GYD-CT-CMS 5778.50 46.77 238.30 5197.24 5130.74 -949.22 -1283.77 5959067.65 674961.97 GYD-CT-CMS 5803.50 47.12 238.38 5214.31 5147.81 -958.81 -1299.32 5959057.70 674946.66 GYD-CT-CMS 5828.50 47.23 238.51 5231.31 5164.81 -968.41 -1314.94 5959047.74 674931.26 GYD-CT-CMS 5853.50 47.47 238.52 5248.24 5181.74 -978.01 -1330.62 5959037.77 674915.81 GYD-CT-CMS Halliburton Com any p Survey Report Company: BP Amoco Date: 6/27/2006 Time: 16:21:16 Page: 4 Field: Prudhoe Bay Co-ordinate(NE) Reference: Weil: 15-02, True North Site: PB DS 15 Vertical (TVD) Reference: 15-02B: 66.5 Well: 15-02 Section (VS) Reference: Well (O.OON,O.OOE,242.10Azi} Wellpath: 15-02BPB2 Surrey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim 'I'U'D Sys"1'~'D N/S E/W b1apN MapE Tool ', ft deg deg ft ft ft ft ft ft 5878.50 47.72 238.60 5265.10 5198.60 -987.64 -1346.37 5959027.78 674900.29 GYD-CT-CMS 5903.50 47.53 238.56 5281.95 5215.45 -997.27 -1362.13 5959017.78 674884.76 GYD-CT-CMS 5928.50 47.63 238.64 5298.82 5232.32 -1006.88 -1377.88 5959007.80 674869.24 GYD-CT-CMS 5953.50 47.70 238.65 5315.65 5249.15 -1016.50 -1393.67 5958997.82 674853.69 GYD-CT-CMS 5978.50 47.92 238.77 5332.44 5265.94 -1026.12 -1409.49 5958987.83 674838.09 GYD-CT-CMS 6003.50 48.26 238.89 5349.14 5282.64 -1035.75 -1425.41 5958977.83 674822.40 GYD-CT-CMS 6028.50 48.21 239.14 5365.79 5299.29 -1045.35 -1441.40 5958967.86 674806.65 GYD-CT-CMS 6053.50 48.30 239.32 5382.44 5315.94 -1054.89 -1457.43 5958957.95 674790.85 GYD-CT-CMS 6078.50 48.69 239.38 5399.01 5332.51 -1064.44 -1473.53 5958948.03 674774.97 GYD-CT-CMS 6103.50 48.84 239.46 5415.49 5348.99 -1074.00 -1489.72 5958938.09 674759.02 GYD-CT-CMS 6128.50 48.84 239.75 5431.94 5365.44 -1083.52 -1505.95 5958928.19 674743.01 GYD-CT-CMS 6153.50 49.05 239.89 5448.36 5381.86 -1093.00 -1522.25 5958918.33 674726.94 GYD-CT-CMS 6178.50 49.29 240.14 5464.70 5398.20 -1102.45 -1538.64 5958908.50 674710.78 GYD-CT-CMS 6203.50 49.36 240.29 5481.00 5414.50 -1111.87 -1555.09 5958898.69 674694.56 GYD-CT-CMS 6228.50 49.30 240.52 5497.29 5430.79 -1121.24 -1571.58 5958888.95 674678.29 GYD-CT-CMS 6253.50 49.37 240.53 5513.58 5447.08 -1130.57 -1588.09 5958879.23 674662.01 GYD-CT-CMS 6278.50 49.71 240.63 5529.81 5463.31 -1139.91 -1604.66 5958869.50 674645.66 GYD-CT-CMS 6303.50 49.73 240.74 5545.97 5479.47 -1149.25 -1621.29 5958859.78 674629.26 GYD-CT-CMS 6328.50 50.16 240.80 5562.06 5495.56 -1158.59 -1637.99 5958850.05 674612.78 GYD-CT-CMS 6353.50 50.30 240.81 5578.05 5511.55 -1167.97 -1654.76 5958840.28 674596.24 GYD-CT-CMS 6378.50 50.07 240.96 5594:06 5527.56 -1177:31 -1671.54 5958830.55 674579.68 GYD-CT-CMS 6403.50 49.91 240.99 5610.13 5543.63 -1186.60 -1688.28 5958820.87 674563.16 GYD-CT-CMS 6428.50 49.91 241.06 5626.23 5559.73 -1195.87 -1705.01 5958811.21 674546.66 GYD-CT-CMS 6453.50 49.77 240.98 5642.35 5575.85 -1205.12 -1721.73 5958801.57 674530.16 GYD-CT-CMS 6478.50 49.59 241.11 5658.53 5592.03 -1214.35 -1738.40 5958791.95 674513.71 GYD-CT-CMS 6503.50 49.66 241.06 5674.72 5608.22 -1223.56 -1755.08 5958782.36 674497.26 GYD-CT-CMS 6528.50 49.30 241.15 5690.97 5624.47 -1232.74 -1771.71 5958772.79 674480.84 GYD-CT-CMS 6553.50 49.06 241.00 5707.31 5640.81 -1241.89 -1788.27 5958763.25 674464.50 GYD-CT-CMS 6578.50 48.95 240.98 5723.71 5657.21 -1251.04 -1804.77 5958753.72 674448.22 GYD-CT-CMS 6603.50 48.66 241.07 5740.17 5673.67 -1260.16 -1821.23 5958744.22 674431.98 GYD-CT-CMS 6628.50 48.45 241.18 5756.72 5690.22 -1269.21 -1837.64 5958734.79 674415.79 GYD-CT-CMS 6653.50 48.43 241.25 5773.31 5706.81 -1278.21 -1854.04 5958725.40 674399.61 GYD-CT-CMS 6678.50 48.10 241.17 5789.95 5723.45 -1287.20 -1870.39 5958716.04 674383.48 GYD-CT-CMS 6703.50 47.83 241.31 5806.69 5740.19 -1296.13 -1886.66 5958706.72 674367.42 GYD-CT-CMS 6728.50 47.91 241.36 5823.46 5756.96 -1305.03 -1902.93 5958697.45 674351.36 GYD-CT-CMS 6753.50 47.57 241.52 5840.27 5773.77 -1313.87 -1919.18 5958688.23 674335.32 GYD-CT-CMS 6778.50 47.51 241.62 5857.15 5790.65 -1322.65 -1935.40 5958679.07 674319.31 GYD-CT-CMS 6803.50 47.42 241.72 5874.05 5807.55 -1331.40 -1951.62 5958669.95 674303.31 GYD-CT-CMS 6828.50 47.13 241.75 5891.01 5824.51 -1340.09 -1967.79 5958660.88 674287.34 GYD-CT-CMS 6853.50 47.19 241.79 5908.01 5841.51 -1348.76 -1983.94 5958651.83 674271.40 GYD-CT-CMS 6878.50 47.46 241.73 5924.96 5858.46 -1357.46 -2000.14 5958642.76 674255.42 GYD-CT-CMS 6903.50 47.19 241.73 5941.90 5875.40 -1366.17 -2016.33 5958633.67 674239.44 GYD-CT-CMS 6928.50 47.09 241.80 5958.91 5892.41 -1374.83 -2032.47 5958624.63 674223.50 GYD-CT-CMS 6953.50 46.84 241.82 5975.97 5909.47 -1383.47 -2048.58 5958615.62 674207.61 GYD-CT-CMS 6978.50 46.91 241.74 5993.06 5926.56 -1392.10 -2064.65 5958606.62 674191.74 GYD-CT-CMS 7003.50 46.97 241.74 6010.13 5943.63 -1400.74 -2080.74 5958597.60 674175.86 GYD-CT-CMS 7028.50 46.79 241.80 6027.22 5960.72 -1409.38 -2096.82 5958588.59 674159.99 GYD-CT-CMS 7053.50 46.98 241.79 6044.30 5977.80 -1418.00 -2112.90 5958579.59 674144.11 GYD-CT-CMS 7078.50 46:78 241.70 6061.39 5994.89 -1426.64 -2128.98 5958570.58 674128.24 GYD-CT-CMS 7103.50 46.61 241.73 6078.54 6012.04 -1435.26 -2145.00 5958561.59 674112.43 GYD-CT-CMS 7128.50 46.35 241.68 6095.75 6029.25 -1443.85 -2160.96 5958552.62 674096.68 GYD-CT-CMS 7153.50 46.46 241.58 6112.99 6046.49 -1452.46 -2176.89 5958543.65 674080.95 GYD-CT-CMS Halliburton Company Survey Report Company: BP Amoco Date: 6/27/2006 Time: 16:21:16 Page: 5 '~ Field: Prudhoe Bay Co-ordinate(~E) Reference: WeII: 15-02, True North '~ Site: PB DS 15 Vertical (TVD) Reference: 15-028: 66.5 Well: 15-02 Section (VS) Reference: WeII (O.OON,O.OOE,242.1DAzi} it Wellpath: 15-02BPB2 Survey Calculation Method: Minimum Curvature Db: Oracle I Survey __ - _ __-- _ -. --- _._ __.----- _ ---_ __ -1 MD Incl Azim TVD Sys TVD N/S ElW MapN MapE; Tool ft deg deg ft ft ft ft ft ft 7178.50 46.90 241.54 6130.14 6063.64 -1461.12 -2192.88 5958534.61 674065.17 GYD-CT-CMS 7203.50 46.78 241.53 6147.24 6080.74 -1469.81 -2208.92 5958525.55 674049.35 GYD-CT-CMS 7228.50 46.54 241.53 6164.40 6097.90 -1478.48 -2224.90 5958516.51 674033.57 GYD-CT-CMS 7253.50 46.38 241.54 6181.62 6115.12 -1487.11 -2240.83 5958507.50 674017.85 GYD-CT-CMS 7278.50 46.46 241.60 6198.86 6132.36 -1495.74 -2256.76 5958498.51 674002.13 GYD-CT-CMS 7303.50 46.20 241.58 6216.12 6149.62 -1504.34 -2272.66 5958489.54 673986.43 GYD-CT-CMS 7328.50 45.88 241.53 6233.47 6166.97 -1512.91 -2288.49 5958480.60 673970.81 GYD-CT-CMS 7353.50 46.03 241.51 6250.85 6184.35 -1521.48 -2304.28 5958471.66 673955.22 GYD-CT-CMS 7378.50 45.95 241.41 6268.22 6201.72 -1530.07 -2320.08 5958462.70 673939.64 GYD-CT-CMS 7403.50 45.85 241.42 6285.62 6219.12 -1538.66 -2335.84 5958453.74 673924.08 GYD-CT-CMS 7428.50 45.83 241.47 6303.04 6236.54 -1547.23 -2351.59 5958444.81 673908.53 GYD-CT-CMS 7453.50 45.49 241.42 6320.51 6254.01 -1555.78 -2367.30 5958435.89 673893.03 GYD-CT-CMS 7478.50 45.46 241.35 6338.04 6271.54 -1564.32 -2382.95 5958426.99 673877.59 GYD-CT-CMS 7503.50 45.25 241.34 6355.61 6289.11 -1572.85 -2398.55 5958418.10 673862.19 GYD-CT-CMS 7528.50 45.00 241.23 6373.25 6306.75 -1581.36 -2414.09 5958409.23 673846.85 GYD-CT-CMS 7553.50 44.77 241.20 6390.96 6324.46 -1589.85 -2429.55 5958400.37 673831.60 GYD-CT-CMS 7578.50 44.66 241.24 6408.73 6342.23 -1598.32 -2444.97 5958391.55 673816.38 GYD-CT-CMS 7603.50 44.40 241.19 6426.55 6360.05 -1606.76 -2460.34 5958382.75 673801.22 GYD-CT-CMS 7628.50 44.25 241.13 6444.43 6377.93 -1615.19 -2475.64 5958373.96 673786.12 GYD-CT-CMS 7653.50 44.12 241.19 6462.36 6395.86 -1623.59 -2490.90 5958365.20 673771.06 GYD-CT-CMS 7678.50 43.75 241.16 6480.36 6413.86 -1631.96 -2506.10 5958356.49 673756.07 GYD-CT-CMS 7703.50 43.64 241.14 6498.44 6431.94 -1640.29 -2521.23 5958347.80 673741.14 GYD-CT-CMS 7728.50 43.53 241.11 6516.55 6450.05 -1648.61 -2536.32 5958339.13 673726.25 GYD-CT-CMS 7753.50 43.32 241.13 6534.71 6468.21 -1656.91 -2551.37 5958330.48 673711.40 GYD-CT-CMS 7778.50 43.22 241.18 6552.91 6486.41 -1665.18 -2566.38 5958321.86 673696.59 GYD-CT-CMS 7803.50 42.94 241.07 6571.17 6504.67 -1673.43 -2581.33 5958313.27 673681.83 GYD-CT-CMS 7828.50 42.64 241.21 6589.52 6523.02 -1681.62 -2596.20 5958304.73 673667.16 GYD-CT-CMS 7853.50 42.53 241.18 6607.92 6541.42 -1689.78 -2611.03 5958296.23 673652.53 GYD-CT-CMS 7878.50 42.20 241.18 6626.39 6559.89 -1697.90 -2625.79 5958287.77 673637.97 GYD-CT-CMS 7903.50 42.12 241.30 6644.93 6578.43 -1705.97 -2640.50 5958279.35 673623.45 GYD-CT-CMS 7928.50 41.82 241.46 6663.51 6597.01 -1713.98 -2655.17 5958271.00 673608.97 GYD-CT-CMS 7953.50 41.15 241.32 6682.24 6615.74 -1721.91 -2669.71 5958262.73 673594.62 GYD-CT-CMS 7978.50 41.09 241.36 6701.07 6634.57 -1729.79 -2684.14 5958254.51 673580.38 GYD-CT-CMS 8003.50 40.99 241.33 6719.93 6653.43 -1737.66 -2698.54 5958246.31 673566.17 GYD-CT-CMS 8028.50 40.70 241.36 6738.84 6672.34 -1745.51 -2712.89 5958238.13 673552.01 GYD-CT-CMS 8053.50 40.47 241.35 6757.83 6691.33 -1753.30 -2727.16 5958230.00 673537.92 GYD-CT-CMS 8078.50 40.24 241.38 6776.88 6710.38 -1761.06 -2741.37 5958221.91 673523.90 GYD-CT-CMS 8103.50 39.94 241.52 6796.01 6729.51 -1768.75 -2755.51 5958213.89 673509.94 GYD-CT-CMS 8128.50 39.80 241.52 6815.19 6748.69 -1776.40 -2769.60 5958205.92 673496.04 GYD-CT-CMS 8153.50 39.54 241.41 6834.44 6767.94 -1784.02 -2783.62 5958197.97 673482.20 GYD-CT-CMS 8178.50 39.27 241.55 6853.75 6787.25 -1791.60 -2797.56 5958190.07 673468.44 GYD-CT-CMS 8203.50 39.18 241.33 6873.12 6806.62 -1799.16 -2811.45 5958182.19 673454.74 GYD-CT-CMS 8228.50 38.90 241.36 6892.54 6826.04 -1806.71 -2825.27 5958174.32 673441.10 GYD-CT-CMS 8253.50 38.62 241.44 6912.03 6845.53 -1814.20 -2839.01 5958166.50 673427.54 GYD-CT-CMS 8278.50 38.61 241.34 6931.57 6865.07 -1821.67 -2852.71 5958158.71 673414.02 GYD-CT-CMS 8303.50 38.35 241.32 6951.14 6884.64 -1829.13 -2866.35 5958150.93 673400.55 GYD-CT-CMS 8328.50 38.00 241.31 6970.79 6904.29 -1836.55 -2879.91 5958143.20 673387.18 GYD-CT-CMS 8353.50 37.96 241.30 6990.50 6924.00 -1843.94 -2893.41 5958135.50 673373.86 GYD-CT-CMS 8378.50 37.53 241.27 7010.26 6943.76 -1851.29 -2906.83 5958127.84 673360.62 GYD-CT-CMS 8403.50 37.39 241.34 7030.11 6963.61 -1858.59 -2920.16 5958120.22 673347.45 GYD-CT-CMS 8428.50 37.31 241.24 7049.98 6983.48 -1865.88 -2933.47 5958112.63 673334.33 GYD-CT-CMS 8453.50 37.06 241.28 7069.90 7003.40 -1873.14 -2946.72 5958105.06 673321.25 GYD-CT-CMS 8478.50 37.22 241.18 7089.83 7023.33 -1880.41 -2959.95 5958097.48 673308.20 GYD-CT-CMS Halliburton Com an p y Survey Report Company: BP Amoco Date: 6/27/2006 Time: 16:21:16 Page: 6 Field: Pru dhoe Bay Co-o rdinate(NE) Reference: Well: 15-02, Tru e North Site: PB DS 15 Verti cal ('1'VD) Reference: 15-026. 66.5 Well: 15- 02 Section (VS) Refer ence: Well (O.OON,O.O OE,242.10Azi) ~Vcllpath: 15- 02BP62 Survey Calculation Method: Minimum Curvature Db: Oracle Survcv MD Incl Azim TVD Sys"1'VD Y/S E!W' MapN MapE 'fool ', ft deg deg ft ft ft ft ft ft 8503.50 37.49 24123 7109.70 7043.20 -1887.71 -2973.24 5958089.87 673295.08 GYD-CT-CMS 8528.50 37.58 241.21 7129.53 7063.03 -1895.05 -2986.59 5958082.22 673281.91 GYD-CT-CMS 8553.50 37.46 241.16 7149.35 7082.85 -1902.38 -2999.93 5958074.58 673268.74 GYD-CT-CMS 8578.50 37.39 241.23 7169.21 7102.71 -1909.70 -3013.24 5958066.95 673255.61 GYD-CT-CMS 8603.50 37.34 241.24 7189.08 7122.58 -1917.01 -3026.54 5958059.33 673242.48 GYD-CT-CMS 8628.50 37.27 241.16 7208.96 7142.46 -1924.30 -3039.82 5958051.73 673229.38 GYD-CT-CMS 8653.50 37.13 241.13 7228.88 7162.38 -1931.60 -3053.06 5958044.12 673216.32 GYD-CT-CMS 8678.50 37.15 241.17 7248.81 7182.31 -1938.88 -3066.28 5958036.53 673203.27 GYD-CT-CMS 8703.50 37.13 241.04 7268.73 7202.23 -1946.18 -3079.49 5958028.93 673190.23 GYD-CT-CMS 8728.50 36.98 241.05 7288.69 7222.19 -1953.47 -3092.68 5958021.33 673177.23 GYD-CT-CMS 8753.50 36.89 241.30 7308.67 7242.17 -1960.71 -3105.84 5958013.78 673164.24 GYD-CT-CMS 8778.50 36.79 241.41 7328.68 7262.18 -1967.90 -3118.99 5958006.29 673151.26 GYD-CT-CMS 8794.00 36.62 241.41 7341.10 7274.60 -1972.33 -3127.13 5958001.67 673143.23 MWD+IFR+MS 8871.84 34.96 237.30 7404.25 7337.75 -1995.49 -3166.29 5957977.60 673104.62 MWD+IFR+MS 8965.92 34.17 231.89 7481.74 7415.24 -2026.37 -3209.77 5957945.71 673061.88 MWD+IFR+MS 9060.61 31.77 225.96 7561.20 7494.70 -2060.12 -3248.63 5957911.06 673023.83 MWD+IFR+MS 9155.26 32.84 217.95 7641.23 7574.73 -2097.70 -3282.34 5957872.70 672991.01 MWD+IFR+MS 9249.97 34.55 212.78 7720.05 7653.55 -2140.54 -3312.68 5957829.17 672961.68 MWD+IFR+MS 9343.25 33.66 213.14 7797.28 7730.78 -2184.43 -3341.13 5957784.63 672934.27 MWD+IFR+MS 9438.39 34.97 212.98 7875.86 7809.36 -2229.38 -3370.39 5957739.01 672906.07 MWD+IFR+MS 9533.33 35.74 212.42 7953.29 7886.79 -2275.61 -3400.07 5957692.10 672877.49 MWD+IFR+MS 9627.76 35.02 211.57 8030.28 7963.78 -2321.97 -3429.04 5957645.07 672849.62 MWD+IFR+MS 9722.00 34.39 211.39 8107.76 8041.26 -2367.73 -3457.06 5957598.67 672822.68 MWD+IFR+MS 9816.69 33.85 216.20 8186.16 8119.66 -2411.85 -3486.57 5957553.87 672794.22 MWD+IFR+MS 9911.30 33.35 216.59 8264.97 8198.47 -2453.99 -3517.63 5957511.01 672764.15 MWD+IFR+MS 9959.72 32.88 217.10 8305.52 8239.02 -2475.16 -3533.49 5957489.48 672748.79 MWD+IFR+MS 10007.01 33.13 221.43 8345.19 8278.69 -2495.09 -3549.79 5957469.17 672732.97 MWD+IFR+MS 10035.59 30.77 224.20 8369.44 8302.94 -2506.19 -3560.06 5957457.84 672722.96 MWD+IFR+MS 10067.14 29.53 236.38 8396.74 8330.24 -2516.29 -3572.17 5957447.46 672711.09 MWD+IFR+MS 10097.71 26.78 246.67 8423.71 8357.21 -2523.20 -3584.78 5957440.26 672698.65 MWD+IFR+MS 10129.76 24.14 257.47 8452.66 8386.16 -2527.48 -3597.81 5957435.67 672685.72 MWD+IFR+MS 10161.59 23.71 257.78 8481.75 8415.25 -2530.25 -3610.42 5957432.61 672673.18 MWD+IFR+MS 10193.78 24.35 260.05 8511.16 8444.66 -2532.77 -3623.28 5957429.79 672660.38 MWD+IFR+MS 10225.47 27.79 265.01 8539.62 8473.12 -2534.54 -3637.08 5957427.70 672646.63 MWD+IFR+MS 10257.00 29.27 273.66 8567.33 8500.83 -2534.69 -3652.11 5957427.20 672631.61 MWD+IFR+MS 10288.72 28.45 282.85 8595.13 8528.63 -2532.51 -3667.22 5957429.02 672616.45 MWD+IFR+MS 10319.93 29.41 294.32 8622.46 8555.96 -2527.70 -3681.46 5957433.50 672602.10 MWD+IFR+MS 10351.56 30.11 298.66 8649.92 8583.42 -2520.69 -3695.50 5957440.17 672587.90 MWD+IFR+MS 10380.91 29.40 298.41 8675.40 8608.90 -2513.73 -3708.30 5957446.83 672574.95 MWD+IFR+MS 10412.41 30.19 306.58 8702.75 8636.25 -2505.33 -3721.46 5957454.92 672561.59 MWD+IFR+MS 10444.31 29.83 306.63 8730.38 8663.88 -2495.82 -3734.27 5957464.13 672548.56 MWD+IFR+MS 10475.62 31.77 308.80 8757.27 8690.77 -2486.00 -3746.95 5957473.64 672535.66 MWD+IFR+MS 10507.50 35.23 313.21 8783.85 8717.35 -2474.44 -3760.19 5957484.88 672522.15 MWD+IFR+MS 10538.26 39.35 317.45 8808.32 8741.82 -2461.18 -3773.26 5957497.84 672508.77 MWD+IFR+MS 10569.54 43.58 321.13 8831.76 8765.26 -2445.47 -3786.74 5957513.23 672494.93 MWD+IFR+MS 10602.27 47.62 323.34 8854.66 8788.16 -2426.98 -3801.05 5957531.38 672480.20 MWD+IFR+MS 10632.00 50.70 325.34 8874.10 8807.60 -2408.70 -3814.15 5957549.34 672466.67 MWD+IFR+MS 10684.38 51.77 327.50 8906.90 8840.40 -2374.68 -3836.73 5957582.82 672443.30 MWD+IFR+MS 10723.02 51.56 326.22 8930.87 8864.37 -2349.30 -3853.30 5957607.80 672426.14 MWD+IFR+MS 10778.96 51.93 325.67 8965.50 8899.00 -2312.91 -3877.90 5957643.61 672400.70 MWD+IFR+MS 10819.28 51.39 326.51 8990.51 8924.01 -2286.66 -3895.54 5957669.43 672382.44 MWD+IFR+MS 10869.93 50.38 325.22 9022.47 8955.97 -2254.13 -3917.59 5957701.43 672359.64 MWD+IFR+MS Halliburton Company Survey Report ~ ' Company: BP Amoco Date: 6/27/2006 Time: 16:21:16 Page: 7 Field: Prudhoe Bay Co-ordinate(E) Reference: Well: 15-02, True North ~ Site: PB DS 15 Vertical (TVD) Reference: 15-02B: 66.5 Well: 15-02 Section (VS) Reference: Well (O.OON,O.OOE,242.10Azi) Weltpath: 15-02BPB2 _ Survey Calculation Method: Minimum Curvature Db: Oracle Surcev MD Incl Azim TVD Sys TVD N1S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 10915.71 49.65 321.62 9051.89 8985.39 -2225.97 -3938.48 5957729.09 672338.09 MWD+IFR+MS 11019.43 48.61 325.37 9119.77 9053.27 -2162.96 -3985.14 5957790.99 672289.97 MWD+IFR+MS 11036.70 47.87 326.96 9131.27 9064.77 -2152.26 -3992.32 5957801.52 672282.55 MWD+IFR+MS 11083.00 47.87 326.96 9162.33 9095.83 -2123.48 -4011.04 5957829.85 672263.16 BLIND TREE = Cameron 4-1/16" 5K WELLHEAD = FMC ACTUATOR = Axelson KB. ELEV = 66.50' BF. ELEV = 63.37' KOP = 3100' Max Angle =93.72 @ 12453' -Datum MD = ?' Datum TV D = ?' SS • 15-02B FROM DRLG -DRAFT ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3153 3151 11 MMG DOME RK 16 07I06t06 3 5133 4747 45 MMG SO RK 20 07/06,'06 2 6982 5996 47 MMG DMY RK 0 06/28/06 1 8374 7007 38 MMG DMY RK 0 06128/06 GAS LIFT MANDRELS 13-3/8" CSG, 72#, L-80, ID = 12.347" 2675' Minimum ID = 3.725" @ 9,832' 4-1 /2" "XN" Nipple 9-5/8" Halliburton FZSV set @ 8815' 5-1/2" tbg chem cut @ 8955' 5-1/2" POGLM (2.34" ID) 8987' PERFORATION SUMMARY REF: Schlumberger TCP ON 06/28/06 ANGLE AT TOP PERF: 87 @ 11230' Note: Refer to w ell file for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 6 11230 - 11460 O 06/28/06 2-1l2" 6 11550 - 11710 O 06/28/06 2-1/2" 6 11940 - 12080 O 06/28/06 2-1/2" 6 12110 - 12220 O 06/28!06 2-112" 6 12250 - 12500 O 06/28!06 2-1l2" 6 12640 - 12710 O 06/28/06 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" ~-1 10677' 2187' 4 112" X Nipple (3.813" ID) 8657' 7" X 9-5/8" Baker G2 ZXP Mech. Packer FETY NOTES: 9767' 4 1/2" X Nipple (3.813" ID) g788' 7" x 4 1/2" Baker S3 Packer 9811' 4 1/2" X Nipple (3.813" ID) 9832' 4 1/2" XN Nipple(3.725" ID)No-Go 9846' 4 1!2" WLEG 9840' 4 1/2" Hanger ! liner top packer 10010' 7" 26# L-80, BTGM Liner 4 1/2" 12.6# L-80 Liner PBTD 12,758' g387' Top of P&A Cement 9700' CIBP 10034' 9-5/8" CSG, 47#, L-80, ID = 8.681" PBTD 11844' 2-7/8" LNR - CT, 6.5#, L-80, .00579 bpf, ID = 2.441" 11905' TD 12390' DATE REV BY COMMENTS DATE REV BY COMMENTS 03/06/82 ORIGINAL COMPLETION 07/06/06 DRF/PAG GLV CO 11!08!96 SIDETRACK 02/06/02 RN/TP CORRECTIONS 09/11/03 CMO/TLP PERFANGLECORRECTION 10/24!05 JNC Proposed Completion 06/30/06 CPC Actual Corr~letion PRUDHOE BAY UNIT WELL: 15-02B PERMfT No: °1961630 API No: 50-029-20697-02 SEC 22, T11 N, R14E, 4301.98' FEL & 2698.93' FNL BP Exploration (Alaska) `~, ~ ~~ IJ d, ~,~ i a ~ ~ CO1~tSERg AT~IO CO1~II-IISS p151T Dave Wesley Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 i' '~ FRANK H. MURKOWSK/, GOVERNOR d~ r 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 15-02B BP Exploration (Alaska) Inc. Permit No: 206-072 Surface Location: 1441' FNL, 285' FWL, SEC. 22, T11N, R14E, UM Bottomhole Location: 2167, FNL, 4407' FEL, SEC. 21, T11N, R14E, UM Dear Mr. Wesley: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, Cathy . Foerster ~a / Commissioner DATED this fwd lay of May, 2006 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASE~IL AND GAS CONSERVATION COMMI~N PERMIT TO DRILL 20 AAC 25.005 ~,.~G A- 5 u. ,± o _. w:_ - ,.... 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class O Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify ifl ~ proposed for ^ Coalbed Methane a Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU 15-026 ``~'~~Z°°` 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 12563 TVD 8941 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 285' FWL R14E UM 1441' FNL SEC 22 T11 N 7. Property Designation: ADL 028306 Pool , , , . , , Top of Productive Horizon: 3301' FNL, 3765' FEL, SEC. 21, T11N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: May 26, 2006 ~ Total Depth: 2167' FNL, 4407' FEL, SEC. 21, T11N, R14E, UM 9. Acres in Properly: 2560 14. Distance to Nearest Property: 24,500' 4b. Location of Well (State Base Plane Coordinates): Surface: x-676223 y-5960047 Zone-ASP4 10. KB Elevation Plan (Height above GL): 66.4 feet 15. Distance to Nearest Well Within Pool: 350' 16. Deviated Wells: Kickoff Depth: 8850 feet Maximum Hole Angle: 96.4 de rees 17. Maximum Anticipated Pressures in psig (see 20 2 .035) Downhole: 3250 Surface: 45 18. Casin Pr ram: S ecifications To - Settln De th -Bottom Quanti of ent, c.f. or sacks Hole Casin Wei ht rade Cou lin L th MD TVD MD TVD includin sta a data 8-1/2" 7" 26# L-80 BTC-M 129 ' 8700' 7260' 9990' 8331' 243 sx Class 'G' ~ 6-1/8" 4-1/2" 12.6# L-80 IBT-M 23' 9840' 8205' 12563' 8941' 331 sx Class 'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redril l and Re-entry Operations) Total Depth MD (ft): 12390 Total Depth TVD (ft): 8976 Plugs (measured): None Effective Depth MD (ft): 11844 Effective Depth TVD (ft) 8994 Junk (measured): None Casing Length ize Cement Volume MD TVD Conductor /Structural 79' 20" 1902 sx Poleset 79' 79' Surface 2675' 13-3/8" 3000 sx Fondu, 400 sx Permafrost 2675' 2675' Intermediate 10034' 9-5/8" 500 sx Class 'G' 10034' 8316' Pr c ion Liner 951' 7" 350 sx Class 'G' 9726' - 10034' 8079' - 8316' Liner 2276' 2-7/8" 145 sx Class 'G' ~ 9692' - 11905' 8053' - 8994' Perforation Depth MD (ft): 10925' - 11841' Perforation Depth TVD (ft): 8953' - 8994' 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Jeff Cutler, 564-4134 Printed Name Q~ve Wesley ,; Title Senior Drilling Engineer " ` Prepared By Name/Number: Si nature f^ %v 2° CG~-~ '' Phone 564-5153 Date '~~ 7/~~(ea Terrie Hubble, 564-4628 Commission Us® Or-ly Permit To Drill Number: ~,C°a~i'° (.~ 7 API Number: 50-029-20697-02-00 Permit Approval Date:.S"~ -Q See cover letter for other requirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales Samples Req'd: ^ Yes~No Mud Log Req'd: ^ Yes~No 'CAS-~ ~ jv ~7 E -~ p ~ Sf> D ~ ~' , 1 HZS Measures: Yes ^ No Directional Survey Req'd: 'Yes ^ No O~'~ 20 /-~A-c zS,o~SS (l•)(~) , c~.~~pyw~l`e ~oI~C` cu.r.d 1!-~PSt y~yaC2~r~.~e.. Gt.n~ ~N~,lec~. APPROVED BY THE COMMISSIO Date ~~ ~~ ' ~ ~ ,COMMISSIONER /Form 10-401 Revised 12/2005 ~ [~' (`' ~ /, Submit In Duplicate • r Well Name: 15-026 Planned Well Summary Well Horizontal Target Ivishak Zone Well 15-02B Sidetrack Type Producer Objective 1 A AFE Number: PBD4P2435 Surface Northin Eastin Offsets TRS Location 5,960,047 676,223 1441' FNL / 285' FWL 11 N, 14E, 22 API Number: 50-029-20697-02 Target Locations Northin Eastin Offsets TRS T1 5,958,094 672,222 1,979' FSL / 1,515' FWL 11 N, 14E, 21 T2 5,958,760 671,902 2,627' FNL / 1,212' FWL 11 N, 14E, 21 Bottom Northin Eastin Offsets TRS Location 5,959,212 671,551 2,167' FNL / 873' FWL 11 N, 14E, 21 Planned KOP: 8,850' MD / 7,381' TVD Planned TD: 12,563' MD / 8,941' TVD Ri Nabors 27E CBE: 32.9' RTE: 66.4 Directional Program A roved Well Ian: Wp09 Exit oint: 8,850' MD / 7,381' TVD Maximum Hole Inclination: 96.4° in the tanned horizontal roduction section. The 15-02 parent well bore will be re-surveyed with Gyrodata's continuous casing multi-shot gyro. After re-surveying all wells pass a Major Risk anti- Proximity Issues: collision surrey with the exception of C-32B. The A/C issues occur in the ' MD in the proposed 15-02B sidetrack with the production section at 12,367 minimum center to center distance of 420'. A Tolerable Collision Risk / Worksheet will be com leted Survey Program: Standard MWD/IIFR/MS. Nearest Well within ool: Well15-23A (current) on production), 350' awa at the closest erf Nearest Pro ert Line 24,500' 15-02B Rotary Sidetrack Page 1 • ~ Logging Program Hole Section: Required Sensors /Service 8 1/2" intermediate: Real time MWD Dir/GR throughout the interval, for tie-in purposes MAD pass with GR 250 above the kickoff oint. 6 1/8" roduction: Real time MWD GR/Densit /Neutron Cased Hole: None Planned O en Hole: None lanned Mud Program Hole Section /operation: Mill window in the 9 5/8" casing to section TD @ 9,990' MD T e Densi Viscosit PV YP API FL HTHP H LSND 0.1 42-52 18-25 22-28 <5.0 <11 9.0-9.5 Hole Section / o eration: Drillin 6 1/8" roduction interval T e Densit LSRV PV YP API FL H FloProSF 8.4-8.6 >25.000 8-15 24-30 4-6 9.0-9.5 Casing /Tubing Program Hole Size Casing/Tubing Size Wt. Grade Connection Length Top and / tvd Bottom and / tvd 8 1/2" 7" 26.0# L-80 BTC-M 1,290' 8,700' / 7,260' 9,990' / 8,331' 6 1/8" 4 ~/z" 12.6# L-80 IBT-M 2,723' 9,840' / 8,205' 12,563' / 8,941' Tubin 4 ~/z" 12.6# L-80 TC-II 9,840' Surface 9,840' / 8,205' Cementing Program Casin Strin 7", 26#, L-80, BTC-M Intermediate Liner Slurry Design Basis: Lead slurry: None planned. Tail slurry: 85' of 7", 26# shoe track, 1140' of 7" X 8-1/2" annulus with 40% excess, 150' of 7" X 9-5/8" annulus and 200' of 4" DP X 9-5/8" annulus Pre-Flush None lanned Fl id S /V l S acer 35 bbls MudPUSH at 12.0 u s equence o ume: Lead Slur None lanned Tail Slur 54.7 bbl / 281.8 cf / 43 xs Class `G', 15.8 ; 1.1 cf/sk. Casin Strin 4-1/2", 12.6#, L-80, IBT-M Production Liner Slurry Design Basis: Lead slurry: none planned Tail slurry: 85' of 4-1/2", 12.6# shoe track, 2573' of 4-1/2" X 6-1/8" annulus with 40% excess, 150' of 4-1/2" X 7" annulus and 200' of 4" DP X 7" annulus Pre-Flush None lanned Fl id S /V l S acer 35bbls MudPUSH at 12.0 u s equence ume: o Lead Slur None lanned Tail Slur 69.0 bbl / 387.4 cf 331 xs Class `G', 15.8 .17 cf/sk. U 15-02B Rotary Sidetrack Page 2 • • Casing /Formation Integrity Testing Test Test Point Test Type Test pressure 9 5/8" casin Bride lu to surface 30 min recorded 3,500 si surface 9 5/8" casin window 20' new formation be and FIT 10.5 EMW 7" casin Float a ui ment to surface 30 min recorded 3,500 si surface 7" casin shoe 20' new formation be and FIT 9.3 EMW 4'/i" roduction liner Float e ui ment to surface 30 min recorded 3,500 si surface Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. BOPE and drilling fluid system schematics are currently on file with the AOGCC. Well Interval: 8 1/2" intermediate interval Maximum antiCl ated BHP: 3,175 si at 7,184' TVD (based on seawater,8.5 ppg, gradient in CM1) Maximum surface ressure: 2,457 pSl (based upon BHP and a full column of gas from TD C~ 0.10 psi/ft) Calculated kick tolerance: Infinite with 10. p ~ EMW FIT Planned BOPE test ressure: 250 si low / ,500 si hi h - 7 da test c cle Pre drillin hase BOPE configuration for 7" Variable Bor ms will remain installed, rather than C/O to 7" pipe rams drilling liner. while running the 7" liner. In the event of a kick the rig will follow the current, best practice, making up a safety valve crossed over to casing thread, then changing elevators and picking up a joint of drill pipe. This confi uration rovides two sets of em to able rams, rather than one. Well Interval: 6 1 /8" roduction interval Maximum antici ated BHP: 3,250 psi at 8,850' TVD Maximum surface ressure: 2,365 psi (based upon BHP and a full column of gas from TD C~3 0.10 psi/ft) Calculated kick tolerance: Infinite with 9.3 EMW FIT. Planned BOPE test ressure: 250 si low / 3,500 si hi h - 14 da test c cle Drillin o erations Planned com letion fluid: 8.4 p seawater / 6.8 Diesel BPXA requests a variance to the provisions of 20 AAC 25.035 (e)(10)C regarding the function pressure test requirement after the use of BOP equipment for other than well control or equivalent purposes, except when the routine use of BOP equipment may have compromised its effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this request will not compromise the integrity of the BOP equipment. Disposal Annular Injection: No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at DS-04. An metal cuttin s should be sent to the North Slo a Borou h. Fluid Handling: All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 ~ for in ection. All Class I wastes are to be hauled to Pad 3 for dis osal. 15-026 Rotary Sidetrack Page 3 • Geologic Prognosis Formation tons and estimated pore pressures Estimated Formation To s Estimated Formation To s Uncertain Hydrocarbon Bearin Estimated Pore Press. Pore Press. Formation TVDss MD +/- eet Yes/No Psi EMW CM1 -7123 Above KOP 0 Planned KOP -7320 8850 THRZ -7564 9146 10 BHRZ -7725 9339 10 LCU/TJD -7733 9348 10 TJC -7905 9554 10 TJB -8080 9763 10 TJA -8180 9883 10 TSGR -8270 9990 10 es TSHA -8305 10032 10 es TSHB -8335 10066 10 es TSHC -8350 10083 10 es TSAD -8385 10122 10 es TCGL -8545 10296 20 es BCGL -8620 10379 20 es 21 TS -8790 10588 20 es 3250 " 7.1 TZ1 B -8850. 10688 20 es TDF -8890 10780 20 es BSAD/Kavik -8930 20 TD Criteria: I Reach planned TD unless drilling conditions deteriorate. Minimum of 800' perfable sand depending on rock quality. Zi B toe a must. Operations Summary Current Condition: / LTSI since 12/03 due to Ann Comm / POGLM's @ 8987' MD and 3203' MD / 11/23/03: Pulled DGLV #2 -pocket left open / 5-1/2" OTIS SSSV nipple Ca3 2116'MD / Minimum ID = 2.34" in POGLM # 1 C~ 3203" MD. / 13-5/8'; 5K FMC Gen 11 wellhead. 15-026 Rotary Sidetrack Page 4 • • Scope * Notify the field AOGCC representative with intent to plug and abandon Pre-Riq Operations: 1. Replace all live Gas Lift valves with Dummy valves and fluid pack as necessary for CT P&A. 2. R/U SL and drift tbg, tag upon upper POGLM @ 3203' MD 3. RIH braided line and retrieve upper POGLM. 4. RU a-line and run gyro surveys down to lower POGLM ~ 8987'. 5. RU CT, RIH to 11,844" MD. Lay in 12.5 bbls of cement, leaving TOC at 9700' MD. POH and RD CT unit. 6. RU SL and drift the 5'/i" tubing, tag up on lower POGLM Q 8987' MD. This will confirm the tubing is clear to the required cut depth of 8,950' MD. 7. RIH with the appropriate jet cutter and cut the 5'/i" tubing at 8,950' MD. 8. Displace the well to clean seawater by circulating down the tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. Freeze protect to 2,200' MD with diesel. 9. Test the 9 5/8" pack-off and tubing hanger seals to 5,000 psi for 30 minutes. Function all Lock Down Screws, repair or replace as needed. 10. Bleed casing and annulus pressures to zero. 11. Set a BPV. Secure the well. Level the pad as necessary. Riq Operations: 1. MI / RU Nabors rig 27E. Pull BPV 2. Circulate out diesel freeze protection and displace the well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE to 3,500psi. Pull TWC 4. R/U. Pull 5'/z" tubing from the cut at 8,950' MD and above. 5. R/U E-line. M/U 8.5" gauge ring /junk basket / CCL. RIH and tag tubing stump. POOH. 6. RIH with HES EZSV on E-line. Set bridge plug at 8,874', as required to avoid cutting a casing collar while milling the window. POOH. R/D E-line. 7. Pressure-test the 9-5/8" casing to 3,500psi for 30 minutes. Record test. U and RIH with 9-5/8" Baker bottom-trip anchor whip stock assembly. Orient whip stock, as desired, and set on bridge plug. Shear off of whip stock. 9. Displace the well to 10.1 ppg LSND based milling fluid. Completely displace the well prior to -~~ ~p - ~ot beginning milling operations. Y'06i'~~. 10. Mill window in 9-5/8" casing at ± 8,850' MD, plus approximately 20' beyond middle of window. '~~ Circulate well bore clean. ,----~ 11. Pull up into 9 5/8" casing and conduct and attempt to FIT t 11. ppg EMW. The rryinimum FIT specified in the Permit to Drill is 10.5 ppg EMW, this still provide finite kick tolerance. POH. 12. M/U 8'/z" Dir/GR assembly. RIH, kick off and drill the 8'/2" intermediate section. 13. Continue drilling ahead in the 8Y2" hole section to the top of the Sag River, per directional proposal. Circulate well clean, short trip to window. POH. ~ 14. Run and cement a 7", 26.0#, L-80 intermediate drilling liner. Test to 3,500 psi. 15. M/U 6-'/e" Dir/GR/Res assembly. RIH to the 7" liner landing collar. 16. Drill out the 7" liner float equipment and cement to the shoe. 17. Displace the well to 8.4 ppg Flo-Pro drilling fluid. 18. Drill out the 7" shoe plus ~20' new formation, pull up into the shoe and conduct a FIT to 10.3 ppg EMW. The minimum FIT specified in the Permit to Drill is 9.3 ppg EMW, this still provides infinite kick tolerance. Drill ahead through Zone 3, completing build section. POH 19. M/U 6-%8" PDC drilling assembly with Dir/GR/Res/Den/ Neu. RIH. 20. MAD pass down from PGOC sending Den/Neu logs to surface real time. 21. Drill ahead to TD in the production interval recording Den/Neu data. 22. Circulate well bore clean, short trip to shoe, circulate. POOH. 23. Run and cement 4'/i", 12.6#, L-80, IBT-M solid production liner. POH. 24. RU SLB. RIH with DPC pert guns. Depth correlate and perforate 1,000' with 2-1/2" PowerJets at 6 spf. 15-026 Rotary Sidetrack Page 5 • • 25. R/U and run a 4~/2", 12.6#, L-80, TC-II tubing completion, stinging into the 4'/z" liner tie back sleeve. ~ 26. Set packer and individually test the tubing and annulus to 3,500psi for 30 minutes. Record each test. 27. Set a BPV. 28. Nipple down the BOPE. Nipple up the tree and test to 5,000psi. 29. Freeze protect the well to 2,200' TVD. Secure the well. 30. Rig down and move off. Post-Riq Operations: 1. MI / RU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. Install gas lift valves. 2. Install well house and instrumentation. Job 1: Move In /Riq Up /Test BOPE Planned Job Time Planned Job Cost 56.6 hours $460,000 includes $305K re-ri costs Reference RP • "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP Issues and Potential Hazards - 15-01 is 120' to the South and will not be required to be shut in to move the rig onto 15-02. 15-23 is 35' to the North; his well will be, requires! to be shut-in for th+~ rig to move. Check the spacing and notify the pad operator to perform the required shut-in prior to moving onto the well. Care should be taken while moving onto the well. Spotters should be employed at all times. - During MI/RU operations, the 15-02 well bore will be secured with the following barriers: o Tubing: the cement P&A plug, kill weight fluid, and a BPV. o IA: Annulus valves and kill weight fluid. o OA: Annulus valve and kill weight fluid. - Prior to pulling the tree, verify there is a static column of seawater to surface and that no pressure exists. - During ND/NU BOPE operations, the 15-02 well bore will be secured with the following barriers: • Tubing: the cement P&A plug, kill weight fluid, and a TWC/blanking plug. • IA: Annulus valves and kill weight fluid. • OA: Annulus valve and kill weight fluid. Drill Site 15 IS not designated as a H2S Site. Standard Operating Procedures for H2S precautions should'6e followed at all times. Recent H2S data from the pad is as follows: Closest well to SHL Latest H2S reading Closest well to BHL Latest H2S reading 15-23 NA 15-23A NA 15-01 NA C-326 NA The maximum level recorded of H2S on the pad wa 50 pm in 15-21A on 02/24/2001. 15-02B Rotary Sidetrack Page 6 • • - Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud Job 2: De-complete Well Planned Job Time Planned Job Cost 41.0 hours $140,000 Reference RP • "De-completions" RP Issues and Potential Hazards - Monitor the well to ensure the fluid column remains static, prior to pulling the completion. - Have all wellhead and completion equipment NORM-tested, following retrieval. - The wellhead is a 13-5/8", 5K FMC Gen II. Check with FMC to ensure all replacement parts and required equipment is available. - Once the stack has been nippled down, verify the hanger thread and type in preparation for de- completion. Be prepared with the appropriate tubing spear, in the event it becomes necessary. Make sure the BOT rep has grapples for both 15.5# and 17# tubing on location. - There is a 5-'/z" Camco BAL-O SSSVN set at 2116'. - Run GR/CCL Log from the bridge plug setting depth to 200' above the KO point after setting the EZSV. Job 3: Run Whip Stock Planned Job Time Planned Job Cost 37.0 hours $230,000 Reference RP • "Whip stock Sidetracks" RP Issues and Potential Hazards - Historical data has the 9-5/8" casing being cemented with 500 sxs of class G cement. Assuming 1.17 cf/sx yield and gauge hole TOC should be 8,166'. Depending on washouts there mayor may not be cement behind the 9-5/8" csg while milling the window. - Once milling is complete, make sure all BOP equipment is operable. Follow standard rig procedure in thoroughly cleaning all areas in which metal cuttings may have settled Job 5: Drill 8-1/2" Intermediate Hole Interval Planned Job Time Planned Job Cost 55.9 hours $270,000 Reference RP • "Shale Drilling, Kingak and HRZ" RP • "Prudhoe Bay Directional Guidelines" • "Lubricants for Torque and Drag Management" RP 15-02B Rotary Sidetrack Page 7 • • Issues and Potential Hazards - Tie MWD - GR back to PDC log from parent wellbore. - The well will be kicked off in the CM1 at 8850' the top of the HRZ is at 9146'. - The directional plan has the wellbore kicking off at 37° then dropping to 33° by the THRZ and holding this angle to the 7" liner point. - Polar plots show of mud weight of 10.1 ppg is required to provide HRZ stability, Maintain mud weight at 10.1 ppg, for the entire intermediate section. Follow all shale drilling practices to minimize potential problems. - KICK TOLERANCE: In the worst-case scenario of 8.3 ppg pore pressure at the CM1 depth, a fracture gradient of 10.5 ppg at the 9-5/8" casing window, and 10.1 ppg mud in the hole, the kick tolerance is infinite. - The above kick tolerance is based on an FIT of 10.5 ppg EMW, a 11.5 ppg EMW FIT will provide an extra margin of safety. Contact the ODE if a FIT of 10.5 ppg EMW is not reached. - The 15-02AB wellbore is not prognosed to cross any faults in the intermediate section and no faults were crossed in the parent wellbore or nearby wells. Phase 6: Run and Cement 7" Intermediate Casing Planned Phase Time Planned Phase Cost 33.1 hours $200,000 Reference RP • "Intermediate Casing and Cementing Guidelines" RP • "Freeze Protecting an Outer Annulus" RP • "Shale Drilling, Kingak and HRZ" RP Issues and Potential Hazards - Swab and surge pressure should be minimized with controlled casing running speeds and by breaking circulation slowly. Excessive swab /surge pressures could initiate HRZ /Kingak instability problems. - Differential Sticking is potentially a problem if lost circulation occurs or if the casing is left stationary across permeable formations. Job 7: Drill 6 1/8" Production Hole Interval Planned Job Time Planned Job Cost 161.8 hours $840,000 Reference RP • "Standard Operating Procedure: Leak-off and Formation Integrity Tests" • "Prudhoe Bay Directional Guidelines" RP Issues and Potential Hazards - KICK TOLERANCE: In the worst-case scenario of 3,250 psi pore pressure in the Ivishak, a fracture gradient 9.3 ppg at the 7" liner shoe, and 8.4 ppg mud in the hole, the kick tolerance is infinite. 15-026 Rotary Sidetrack Page 8 • ~ - The above kick tolerance is based on an FIT of 9.3 ppg EMW, contact the ODE if this EMW is not reached. - The directional plan has the wellbore entering the Sag River at 33°, the angle will then be dropped to 24° through the Zone 3 conglomerate. The well will then be landed in Zone 1 A and drilled horizontally with atoe-up into Zone 1 B prior to TD at 12,563' MD - The production interval is planned to be drilled with two bits. An insert bit will be utilized to drill the conglomerate and land the well in Zone 1 B, a PDC bit will then be used to drill the horizontal section. - 15-026 is prognosed to cross one fault in Zone 2, 10975'-11125' MD. Lost circulation events recorded from the surrounding wells are; 15-23A (30 bbls), C-31 (3900 bbls at 8552 ft), and 3 losses were recorded in C-31 A (total of 940 bbls, at reservoir level). None of these events were associated with fault crossings. No losses occurred in the parent well and no mapped faults are crossed by the proposed well, thus the risk of lost circulation events should be slightly lower than average. Job 9: Run and Cement 4~h" Production Liner Planned Job Time Planned Job Cost 19.2 hours $235,000 Issues and Potential Hazards - The completion design is to run a 41/2", 12.6#, L-80, IBT-M liner over the production interval. - Differential sticking is possible. The 8.4 ppg Flo-Pro will be 673 psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. - Sufficient 4-1h" liner will be run to extend 150' back up into the 7" liner shoe. - Ensure the 4-1/2" liner top packer is set prior to POH. Job 10: DPC Perforate Well Planned Job Time Planned Job Cost 33.1 hours $290,000 Hazards and Contingencies - The production interval of the well will be DPC perforated prior to running the completion. Be prepared for losses upon firing guns. Ensure all responsibilities are clearly communicated with respect to perforating guns safety. Watch hole fill closely while POH with pert guns. - The Asset will provide a minimum clean out depth. This will define how far off depth the guns can be and still be fired without coming out of the hole to perform a clean out trip in the event the guns cannot reach tag the landing collar due to cement/fill. Reference RPs • DPC Perforating RP • Schlumberger DPC Perforating Guidelines 15-026 Rotary Sidetrack Page 9 • • Job 12: Run 4'/i" 13-Cr Completion Planned Job Time Planned Job Cost 28.3 hours $495,000 Reference RP • "Completion Design and Running" RP • "Tubing connections" RP Issues and Potential Hazards - 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. - The completion will be a 4'/i", 12.6#, 13-Cr, VamTop production tubing string, stinging into the 4 %2" liner tieback sleeve. Job 13: ND/NU/Release Rig Planned Job Time Planned Job Cost 14.4 hours $40,000 Reference RP • "Freeze Protecting an Inner Annulus" RP Issues and Potential Hazards - 15-01 is 120' to the South and will not be required to be shut in to move the rig off of 15-02. 15-23 is 35' to the North; this well will be required to be shut-in for the rig to move. Check the spacing and notify the pad operator to perform the required shut-in prior to moving off of the well. Care should be taken while moving off of the well. Spotters should be employed at all times. 15-02B Rotary Sidetrack Page 10 u o h F- ~ ~ c c ~= in ra m m m m N a° a° a° l `~ F . ao ? - o r V MMr NM~G ~DMhhM~hr xx00TN OMhrT~O ~O x.o A 41 h0 l hTN 9 v. N NM,~x~GN~ONN x^Mr Mh rrr ,--1 ROVIT OOni rIMTOVYi vai .Or ~~b C N F o o MMMMOOCYY?OVVev F - ~ 13 - ° - f~ ^ - o o z ~Q J - v. ~}' ~ ~+ oooohor MO~cQOMO 0000 TOOCOO~n ADO-O o,oox c~~o~no oao - t o ? N0 O z ~ ~ ~ ~ F e ~ "' '° _ z tiara ao ~ av`O s J - ~rh i V ~ a_i m ~ ~ x 000000000000000 ^ Y ~ .~ ~ ~ 0000 h0~000000000 j N 0 0 N O N 0 0 0 0 0 0 0 0 - - 3 O O O O O tie \ qoq ~ d ~ ~ + ^ ~ ,pMp M? ~ 0 T m ~ '~ _ In 3 NMOr-NO TTT-0 ,h.,arNx.-rorr0aa1~0 ??? ' ' ° ~ ~ ~ ~ '~ C _ ~' ~ '~ ~ ;y + ~.o sir niv h~^a1~~~-i .~i ono NMNr]O-~O?r0~/~MOnIT --nlh.ora00NM 0h~o ,c rn ~0N 1 z -rl R U < c - W 0 MMM~OO'a7~~R i ~ ~ ~ i ~ Z ~0? 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Fm..IFFFF FFFFFm NFF ~ s hlaeo~~rvz ne vv`r'i~~T~o d ~O b~OQ~'1 n10~~OMN~Ox xrT F 0 OMOh~OxT M~Ox NTr xxr TOOO ~NMh~Or T T T T T T T 0 0 0 0 0 0 0~ 0 ~ L 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ec<ee0vvcvaevva0 ~ c ,ov~c---.o .c-.o .o-__- d' Q NxT~00OM.OT-00xh-Vl `~ > ~n~~ao»z»zz°x~zaozz tz F. ~ O~NMOh.O Z -NMeh~orxa------- -- °. K _ III K ~p O N N O O - R N U 7 j 0 0 S ~ £° ~ ~ ~ §~~~ S ~ ~ Y ~~~~ =y~~,~ - ~~~~ 'd'' 3 2 J O r ~~!/U00£] 4td~a ~eo!uan alu,£ S er -Sun P rY BP Planning Report Company: BP Amoco Date: 5/17/2006 Time: 08:54:11 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 15-02, True North Site: PB DS 15 Vertical (TVD) Reference: 28.5+32.9 61.4 Wells 15-02 Section (VS) Reference: Well (O.OON,O.OOE,261.22Azi) Wellpath: Plan 15-02B Survey Calculation Method: Minimum Curvature Db: Oracle Plan: 15-028 wp09 Date Composed: 9/7/2005 Version: 32 Principal: Yes Tied-to: From: Definitive Path Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: PB DS 15 TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5958837.36 ft Latitude: 70 17 35.236 N From: Map Easting: 676296.98 ft Longitude: 148 34 21.213 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.34 deg Well: 15-02 Slot Name: 02 15-02 Well Position: +N/-S 1210.77 ft Northing: 5960046.65 ft Latitude: 70 17 47.144 N +E/-W -45.55 ft Easting : 676223.05 ft Longitude: 148 34 22.541 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 9990.25 8331.40 7.000 8.500 T' 12563.00 8941.40 4.500 6.125 4 1 /2" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 0.00 CM1 0.00 0.00 9146.52 7625.40 THRZ 0.00 0.00 9338.93 7786.40 BHRZ 0.00 0.00 9348.49 7794.40 LCUlTJD 0.00 0.00 9554.04 7966.40 TJC 0.00 0.00 9763.18 8141.40 TJB 0.00 0.00 9882.69 8241.40 TJA 0.00 0.00 9990.25 8331.40 TSGR 0.00 0.00 10031.87 8366.40 TSHA 0.00 0.00 10066.50 8396.40 TSHB 0.00 0.00 10083.49 8411.40 TSHC 0.00 0.00 10122.46 8446.40 TSAD 0.00 0.00 10296.53 8606.40 TCGL 0.00 0.00 10378.77 8681.40 BCGL 0.00 0.00 10588.57 8851.40 21 TS 0.00 0.00 10687.95 8911.40 TZ1 B 0.00 0.00 10779.63 8951.40 TDF 0.00 0.00 0.00 BSAD 0.00 0.00 Targets Map Map <-- Latitude --> <- Longitude -> Name Description TVD +N/-S +E/-W Northing Easting Deg Min. Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 15-02B T4 8941.40 -724.79 -4690.00 5959212.15 671551.64 70 17 40.002 N 148 36 39.232 W 15-02B T3 8976.40 -1185.00 X350.00 5958760.06 671902. 31 70 17 35.477 N 148 36 29.315 W 15-028 T2 8981.40 -1858.42 X046.00 5958094.00 672222.00 70 17 28.856 N 148 36 20.444 W S er -Sun P rY BP Planning Report Company: BP Amoco Date: 5/17/2006 Time: 08:54:11 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: WeIL 15-02, True North Site: P B DS 15 Vertical (TVD) Reference: 28. 5+32.9 61.4 Well; 15-02 Section (VS) Reference: Well (O.OON,O.OOE,261.22Azi) Wellpath: Plan 15-026 Survey Calculation Method: Minimum Curvature Db: Oracle Plan Section Information MD Incl Azim TVD +N/_S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/1008 deg 8850.00 36.69 239.59 7381.53 -2050.59 -3126.35 0.00 0.00 0.00 0.00 8870.00 36.97 235.61 7397.54 -2057.01 -3136.47 12.00 1.38 -19.89 -85.00 9070.00 33.20 223.30 7561.38 -2130.95 -3223.79 4.00 -1.88 -6.15 237.00 10011.28 33.20 223.30 8349.00 -2506.05 -3577.29 0.00 0.00 0.00 0.00 10288.80 24.22 298.04 8599.34 -2535.50 -3682.89 12.50 -3.24 26.93 135.95 10375.04 24.22 298.04 8678.00 -2518.87 -3714.11 0.00 0.00 0.00 0.00 10949.47 90.00 340.48 8981.40 -2141.17 -3945.74 12.60 11.45 7.39 45.07 11249.47 90.00 340.48 8981.40 -1858.42 -4046.00 0.00 0.00 0.00 0.00 15-026 T2 11342.04 90.26 336.78 8981.19 -1772.23 -4079.72 4.00 0.28 -3.99 -86.03 11768.23 90.26 336.78 8979.29 -1380.56 -4247.73 0.00 0.00 0.00 0.00 11989.15 91.24 328.00 8976.40 -1185.00 -4350.00 4.00 0.45 -3.98 -83.56 15-02B T3 12141.31 96.42 324.79 8966.24 -1058.61 -4433.97 4.00 3.40 -2.11 -31.64 12263.38 96.42 324.79 8952.60 -959.50 -4503.91 0.00 0.00 0.00 0.00 12463.44 90.00 320.00 8941.40 -801.39 -4625.72 4.00 -3.21 -2.39 -143.13 12563.44 90.00 320.00 8941.40 -724.79 -4690.00 0.00 0.00 0.00 0.00 15-02B T4 Survey MD Incl Azim TVD Sys TVD VS N/S E/W DLS MapN MapE TooUCo ft deg deg ft ft ft ft ft deg/100ft ft ft 8850.00 36.69 239.59 7381.53 7320.13 3402.85 -2050.59 -3126.35 0.00 5957923.46 673145.84 Start Dir 1 8870.00 36.97 235.61 7397.54 7336.14 3413.83 -2057.01 -3136.47 12.00 5957916.80 673135.87 Start Dir 4/ 8900.00 36.33 233.91 7421.61 7360.21 3429.87 -2067.34 -3151.10 4.00 5957906.13 673121.50 MWD+IFR 9000.00 34.38 227.87 7503.19 7441.79 3479.79 -2103.74 -3195.99 4.00 5957868.69 673077.47 MWD+IFR 9070.00 33.20 223.30 7561.38 7499.98 3511.43 -2130.95 -3223.79 4.00 5957840.84 673050.31 End Dir 9100.00 33.20 223.30 7586.48 7525.08 3524.39 -2142.91 -3235.06 0.00 5957828.62 673039.33 MWD+IFR 9146.52 33.20 223.30 7625.40 7564.00 3544.48 -2161.44 -3252.53 0.00 5957809.68 673022.30 THRZ 9200.00 33.20 223.30 7670.15 7608.75 3567.59 -2182.76 -3272.62 0.00 5957787.90 673002.72 MWD+IFR 9300.00 33.20 223.30 7753.83 7692.43 3610.79 -2222.61 -3310.17 0.00 5957747.19 672966.11 MWD+IFR 9338.93 33.20 223.30 7786.40 7725.00 3627.60 -2238.12 -3324.79 0.00 5957731.34 672951.86 BHRZ 9348.49 33.20 223.30 7794.40 7733.00 3631.73 -2241.93 -3328.38 0.00 5957727.45 672948.36 LCU/TJD 9400.00 33.20 223.30 7837.50 7776.10 3653.99 -2262.46 -3347.73 0.00 5957706.47 672929.51 MWD+IFR 9500.00 33.20 223.30 7921.18 7859.78 3697.19 -2302.31 -3385.28 0.00 5957665.75 672892.90 MWD+IFR 9554.04 33.20 223.30 7966.40 7905.00 3720.54 -2323.84 -3405.58 0.00 5957643.75 672873.12 TJC 9600.00 33.20 223.30 8004.86 7943.46 3740.39 -2342.16 -3422.84 0.00 5957625.04 672856.29 MWD+IFR 9700.00 33.20 223.30 8088.53 8027.13 3783.59 -2382.01 -3460.39 0.00 5957584.32 672819.68 MWD+IFR 9763.18 33.20 223.30 8141.40 8080.00 3810.89 -2407.19 -3484.12 0.00 5957558.59 672796.55 TJ B 9800.00 33.20 223.30 8172.21 8110.81 3826.79 -2421.86 -3497.95 0.00 5957543.60 672783.08 MWD+IFR 9882.69 33.20 223.30 8241.40 8180.00 3862.51 -2454.81 -3529.00 0.00 5957509.93 672752.80 TJA 9900.00 33.20 223.30 8255.88 8194.48 3869.99 -2461.71 -3535.50 0.00 5957502.89 672746.47 MWD+IFR 9990.25 33.20 223.30 8331.40 8270.00 3908.98 -2497.67 -3569.39 0.00 5957466.14 672713.43 7" 10000.00 33.20 223.30 8339.56 8278.16 3913.19 -2501.56 -3573.06 0.00 5957462.17 672709.86 MWD+IFR 10011.28 33.20 223.30 8349.00 8287.60 3918.07 -2506.05 -3577.29 0.00 5957457.57 672705.73 Start Dir 1 . 10031.87 31.40 226.74 8366.40 8305.00 3926.93 -2513.83 -3585.06 12.50 5957449.62 672698.14 TSHA 10066.50 28.60 233.35 8396.40 8335.00 3941.71 -2524.97 -3598.29 12.50 5957438.17 672685.18 TSHB 10083.49 27.36 237.03 8411.40 8350.00 3948.86 -2529.52 -3604.83 12.50 5957433.47 672678.75 TSHC 10100.00 26.26 240.90 8426.14 8364.74 3955.75 -2533.36 -3611.20 12.50 5957429.48 672672.47 MWD+IFR 10122.46 24.94 246.64 8446.40 8385.00 3964.99 -2537.65 -3619.89 12.50 5957424.99 672663.88 TSAD 10200.00 22.43 270.12 8517.56 8456.16 3995.50 -2544.12 -3649.76 12.50 5957417.82 672634.17 MWD+IFR 10288.80 24.22 298.04 8599.34 8537.94 4026.92 -2535.50 -3682.89 12.50 5957425.66 672600.86 End Dir : 1 10296.53 24.22 298.04 8606.40 8545.00 4029.46 -2534.01 -3685.69 0.00 5957427.09 672598.03 TCGL 10300.00 24.22 298.04 8609.56 8548.16 4030.60 -2533.34 -3686.94 0.00 5957427.73 672596.76 MWD+IFR 10375.04 24.22 298.04 8678.00 8616.60 4055.23 -2518.87 -3714.11 0.00 5957441.55 672569.26 Start Dir 1 . 10378.77 24.55 298.84 8681.40 8620.00 4056.46 -2518.14 -3715.47 12.60 5957442.26 672567.89 BCGL 10400.00 26.53 303.03 8700.55 8639.15 4063.49 -2513.42 -3723.30 12.60 5957446.78 672559.94 MWD+IFR 10500.00 36.95 316.68 8785.59 8724.19 4097.31 -2479.25 -3762.81 12.60 5957480.02 672519.65 MWD+IFR Went 0 0 ~S ~S '0 AS 4S AS AS ~S 1S ~S AS AS r1S ~S ~S ~g AS AS r1S S err -Sun P Y BP Planning Report Company: BP Amoco Date: 5/17/2006 Time: 08:54:11 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 15-02, True North Site: PB DS 15 Vertical (TVD) Reference: 28.5+32.9 61.4 Well: 15-02 Section (VS) Reference: Well (O.OON,O.OOE,261.22Azi) Wellpath: Plan 15-028 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD ft 10588.57 10600.00 10687.95 10700.00 10779.63 10800.00 10900.00 10949.47 11000.00 11100.00 11200.00 11249.47 11300.00 11342.04 11400.00 11500.00 11600.00 11700.00 11768.23 11800.00 11900.00 11989.15 12000.00 12100.00 12141.31 12200.00 12263.38 12300.00 12400.00 12463.44 12500.00 12563.00 12563.44 Incl deg Atim deg TVD ft Sys TVD ft VS ft N/S ft 46 .98 324. 03 8851.40 8790.00 4127. 29 -2433.54 48 .31 324. 79 8859.10 8797.70 4131. 10 -2426. 67 58 .63 329. 81 8911.40 8850.00 4159. 50 -2367. 19 60 .06 330. 41 8917.54 8856.14 4163. 23 -2358. 20 69 .56 333. 98 8951.40 8890.00 4186. 60 -2294. 51 72 .01 334. 82 8958.10 8896.70 4192. 16 -2277. 16 84 .04 338. 66 8978.83 8917.43 4216. 50 -2187. 45 90 .00 340. 48 8981.40 8920.00 4226. 46 -2141. 17 90 .00 340. 48 8981.40 8920.00 4235. 88 -2093. 55 90 .00 340. 48 8981.40 8920.00 4254. 51 -1999. 30 90 .00 340. 48 8981.40 8920.00 4273. 14 -1905. 05 90 .00 340. 48 8981.40 8920.00 4282. 36 -1858. 42 90 .14 338. 46 8981.34 8919.94 4292. 65 -1811. 10 90 .26 336. 78 8981.19 8919.79 4302. 53 -1772. 23 90 .26 336. 78 8980.93 8919.53 4316. 97 -1718. 97 90 .26 336. 78 8980.49 8919.09 4341. 89 -1627. 06 90 .26 336. 78 8980.04 8918.64 4366. 82 -1535. 16 90 .26 336. 78 8979.59 8918.19 4391. 74 -1443. 26 90 .26 336. 78 8979.29 8917.89 4408. 75 -1380. 56 90 .40 335. 52 8979.11 8917.71 4417. 00 -1351. 50 90 .85 331. 55 8978.02 8916.62 4447. 37 -1262. 01 91 .24 328. 00 8976.40 8915.00 4479. 95 -1185. 00 91 .61 327. 77 8976.13 8914.73 4484. 24 -1175. 82 95 .01 325. 67 8970.35 8908.95 4525. 62 -1092. 37 96 .42 324. 79 8966.24 8904.84 4543. 63 -1058. 61 96 .42 324. 79 8959.68 8898.28 4569. 59 -1010. 96 96 .42 324. 79 8952.60 8891.20 4597. 61 -959. 50 95 .24 323. 91 8948.88 8887.48 4614. 08 -929. 89 92 .04 321. 51 8942.53 8881.13 4661. 70 -850. 51 90.00 320.00 8941.40 8880.00 4693.85 -801.39 90.00 320.00 8941.40 8880.00 4712.79 -773.39 90.00 320.00 8941.40 8880.00 4745.44 -725.12 90.00 320.00 8941.40 8880.00 4745.67 -724.79 E/W DLS MapN ft deg/100ft ft -3800.21 12.60 5957524.84 -3805.12 12.60 5957531.59 -3843.05 12.60 5957590.16 -3848.22 12.60 5957599.02 -3881.71 12.60 5957661.91 -3890.02 12.60 5957679.05 -3928.50 12.60 5957767.84 -3945.74 12.60 5957813.69 -3962.62 0.00 5957860.90 -3996.04 0.00 5957954.34 -4029.46 0.00 5958047.77 -4046.00 0.00 5958094.00 -4063.72 4.00 5958140.88 -4079.72 4.00 5958179.37 -4102.57 0.00 5958232.08 -4141.99 0.00 5958323.02 -4181.41 0.00 5958413.97 -4220.83 0.00 5958504.92 -4247.73 0.00 5958566.97 -4260.57 4.00 5958595.71 -4305.13 4.00 5958684.13 -4350.00 4.00 5958760.06 -4355.76 4.00 5958769.11 -4410.53 4.00 5958851.24 -4433.97 4.00 5958884.44 -4467.60 0.00 5958931.29 -4503.91 0.00 5958981.88 -4525.15 4.00 5959010.98 -4585.60 4.00 5959088.91 -4625.72 4.00 5959137.08 -4649.22 0.00 5959164.52 -4689.72 0.00 5959211.82 -4690.00 0.00 5959212.15 MapE TooUCo. ft 672481.19 21TS 672476.11 MWD+IFR 672436.80 TZ1 B 672431.43 MWD+IFR 672396.46 TDF 672387.74 MWD+IFR 672347.17 MWD+IFR 672328.85 End Dir : 1 672310.86 MWD+IFR 672275.24 MWD+IFR 672239.62 MWD+IFR 672222.00 15-026 T2 672203.18 MWD+IFR 672186.27 End Dir : 1 672162.18 MWD+IFR 672120.61 MWD+IFR 672079.05 MWD+IFR 672037.49 MWD+IFR 672009.13 Start Dir 4/ 671995.61 MWD+IFR 671948.97 MWD+IFR 671902.31 15-026 T3 671896.33 MWD+IFR 671839.63 MWD+IFR 671815.40 End Dir : 1 671780.67 MWD+IFR 671743.16 Start Dir 4/ 671721.24 MWD+IFR 671658.95 MWD+IFR 671617.69 End Dir : 1 671593.54 MWD+IFR 671551.93 4 1 /2" 671551.64 15-026 T4 • S err -Sun P Y Anticollision Report Company: BP Amoco Date: 10/25/2005 Time: 15:15:37 Page: 1 Field: Prudhoe Bay Reference Site: PB DS 15 Co-ordinate(NE) Refe rence: Well: 15-02, True North Reference Well: 15-02 Vertical (TVD) Reference: 28.5+32.9 61.4 Reference Wellpath: Plan 15-02B Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are TIIreYd~rradls in this fl2tdlcipal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Modei: ISCWSA Ellipse Depth Range: 8850.00 to 12563.44 ft Scan Method: Trav Cylinder North Maximum Radius: 1453.49 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 9/7/2005 Validated: No Version: 3 Planned From To Survey Toolcode Tool Name ft ft 98.40 8850.00 1 : Spent'-Sun BOSS gyro multi (98.40-11 00~3AQ-4aT-CMS Gyrodata cont.casing m/s 8850.00 12563.44 Planned: 15-02B wp09 V31 MWD+IFR+MS MWD +IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft in in 9990.25 8331.40 7.000 8.500 7" 12563.00 8941.40 4.500 6.125 4112" Summary <---- Offset Wellpath -- Site Well ------> Wellpath Reference MD Offset MD Ctr-Ctr No-Go Allowable Distance Area Deviation Warning / ft ft ft ft ft PB C Pad C-31 C-31 V3 12268.84 11733.62 849.03 197.05 651.98 Pass: Major Risk PB C Pad C-31 C-31A V1 10845.33 12675.00 1408.06 178.43 1229.63 Pass: Major Risk PB C Pad C-31 C-31 B V2 12493.16 11375.00 1424.95 186.73 1238.22 Pass: Major Risk PB C Pad C-32 C-32A V2 Out of range PB C Pad C-32 C-326 V3 12367.46 12484.68 419.86 0.00 419.86 Pass: Minor 1/200 PB C Pad C-41 C-41 V1 Out of range PB DS 07 07-28 07-28A V3 10450.00 13550.00 767.45 209.14 558.31 Pass: Major Risk PB DS 07 07-28 07-28AL1 V2 10578.87 13733.15 233.59 197.91 35.67 Pass: Major Risk PB DS 15 15-01 15-01 V4 Out of range PB DS 15 15-01 15-01A V2 10289.23 11175.00 1037.08 113.78 923.31 Pass: Major Risk PB DS 15 15-01 15-01 B V6 Out of range PB DS 15 15-02 15-02 V1 8850.00 8850.00 0.00 0.00 0.00 Pass: NOERRORS PB DS 15 15-02A 15-02A V1 8850.00 8850.00 0.00 No Reference Casings PB DS 15 15-02APB1 15-02APB1 V1 8850.00 8850.00 0.00 No Reference Casings PB DS 15 15-03 15-03 V1 Out of range PB DS 15 15-04 15-04 V5 Out of range PB DS 15 15-04 15-04A V2 Out of range PB DS 15 15-05 15-05 V5 Out of range PB DS 15 15-05 15-05A V2 Out of range PB DS 15 15-05 15-05AP61 V2 Out of range PB DS 15 15-06 15-06 V1 Out of range PB DS 15 15-06A 15-06A V4 Out of range PB DS 15 15-06AP61 15-06AP61 V2 Out of range PB DS 15 15-23 15-23 V1 11521.81 11629.90 118.31 75.49 42.83 Pass: Major Risk PB DS 15 15-23 15-23A V4 12485.60 11300.00 544.87 117.07 427.79 Pass: Major Risk PB DS 15 15-24 15-24 V1 Out of range PB DS 15 15-26 15-26 V1 Out of range PB DS 15 15-26 15-26A V3 Out of range PB DS 15 15-26 15-266 V5 Out of range PB DS 15 15-32 15-32 P61 V1 Out of range PB DS 15 15-32 15-32 V1 Out of range PB DS 15 15-39 15-39 V1 Out of range PB DS 15 15-39 Plan 15-39A VO Plan: 1 Out of range PB DS 15 15-41 15-41 V1 Out of range PB DS 15 15-41 15-41A V2 Out of range PB DS 15 15-41 15-41 B V3 Out of range PB DS 15 15-41 15-41 BP61 V1 Out of range PB DS 15 15-41 Plan#3 15-41A VO Plan: Out of range PB DS 15 15-47 15-47 V1 Out of range PB DS 15 15-48 15-48 V1 Out of range PB DS 15 15-48 15-48A V2 Out of range TREE = FMC GEN 2 ELLHEAD = FMC _ ACTUATOR = AXELSON KB. ELEV = 63' BF. ELEV - ~ KOP = 3100' Max Angle = 94 @ 12351' Datum MD = 10753' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~-{ 2675' Minimum ID = 2.34" @ 3203' 5-1/2"AVA POGLM I TOP OF 2-7/8" LNR - CT 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" ~ 9721' TOP OF 4-1 /2" LNR 9721' TOP OF 7" LNR 9726' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE *1 '2 3203 8987 3200 7492 12 37 DWP DWP BK BK ' POGLMS ; ID = 2.34" 9629' 4-1/2" SCOOP GUIDE G SEAL ASSY 9632' 3-1/2" X 2-7/8" XO~ 9690' 5-1/2" BOT PBRASSY (BEHIND CT LNR) 9710' 9-5/8" X 5-1/2" BOT 3-H PKR (BEHIND CT LNR} 9721' 5-1/2" X 4-1/2" XO (BEHIND CT LNR) 97$0' --~ 4-1 /2" OTIS XN NIP (BEHIND CT LNR), ID = 3.725" 4-1/2" TBG-PC, 12.6#, N-80, .0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, L-80, ID = 8.681" ~-~ 10034' PERFORATION SUMMARY REF LOG: SWS RST ON 06/10/98 ANGLE AT TOP PERF: 67 @ 10925' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10925 - 10940 O 04/28/01 2" 6 10955 - 10995 O 03/13/00 2" 6 11010 - 11070 O 03/13/00 2-1 /8" 4 11251 - 11525 O 11 /07/96 2-1 /8" 4 11550 - 11841 O 11 /07/96 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" PBTD 2-7/8" LNR - CT, 6.5#, L-80, .00579 bpf, ID = 2.441" ~1 9791' 4-1/2" BOT SHEAROUT SUB (BEHIND CT LNR) 9792' 4-1/2" TUBING TAIL (BE}iIND CT LNR) 9~80~ ELMD TT LOGGED 04/11/90 (BEHIND CT LNR) 7" SIDETRACK WINDOW 10677' - 10683' 11844' 11905' 12390' DATE REV BY COMMENTS DATE REV BY COMMENTS 03/06/82 ORIGINAL COMPLETION 11/08/96 SIDETRACK 02/06/02 RN/TP CORRECTIONS 09/11/03 CMO/TLP PERFANGLECORRECTION PRUDHOE BAY UNTT WELL: 15-02A PERMIT No: 1961630 API No: 50-029-20697-01 SEC 22, T11 N, R14E, 4301.98' FEL & 2698.93' FNL BP Exploration (Alaska) 15 s~o ~~ '4FETY NOTES: POGLM'S @ 3203' & 8987', ID = 2.34" - 70° @ 10970' AND 90° @ 11120' 2116' S-1/2" OTIS ROM SSSV NIP, ID = 4.562" TREE = FMC GEN 2 LHEAD = FMC 'ACTUATOR= AXELSON KB. E1EV = 63' BF. ELEV = ? KOP = 3100' Max Angle = 94 @ 12351' Datum MD = 10753' Datum TV D = 8800' SS • 13-3/8" CSG, 72#, L-80, ID = 12.347" 2675' Minimum ID = 3.725" @ 9,810' 4-1/2" "XN" Nipple 15 ~O ~ ~ ~ AFETY NOTES: POGLM'S @ 3203' 8 8987', Proposed Completion ID = 2.34° - 70° @ 10970' AND 90° @ 11120' 1 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3 2 1 9-5/8" Halliburton EZSV set @ 8874' 5-1/2" tbg Chem cut @ 8950' 5-1/2" POGLM (2.34" ID) 8987' PERFORATION SUMMARY REF LOG: SWS RST ON 06/10/98 ANGLE AT TOP PERF: 67 @ 10925' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" ~-~ 10677' 8700' 7" X 9-5/8" Baker S-3 Packer I 9750' 7" x 4 1/2" Baker S3 Packer 9770' 4 1/2" X Nipple (3.813" ID) 9790' 4 1/2" X Nipple (3.813" ID) 9810' 4 1/2" XN Nipple (3.725" ID) 9,830' 4 1/2" WLEG 9840' 4 1/2" Hanger /liner top packer I o. 9990' 7", 26#, L-80, IBT-M Liner ;~ ~ a ~ ,. 'e' w . ~ 4 1/2" 12.6# L-80 Liner PBTD 12,546' 9700' Top of P&A Cementl a ~ ~ ~ l 10034' 9-5/8" CSG, 47#, L-80, ID = 8.681" PBTD 11844' 2-7/8" LNR - CT, 6.5#, L-80, .00579 bpf, ID = 2.441 ^ 11905' TD 12390' DATE REV BY COMMENTS DATE REV BY COMMENTS 03/06/82 ORIGINAL COMPLETION 11/08/96 SIDETRACK 02/06/02 RWTP CORRECTIONS 09(11103 CMO/TLP PERF ANGLE CORRECTION 10/24/05 JNC Proposed Completion PRUDHOE BAY UNTf WELL: 15-026 PERMIT No: 1961630 API No: 50-029-20697-02 SEC 22, T11 N, R14E, 4301.98' FEL & 2698.93' FNL BP F~cploration (Alaska) • • First National Bank Alaska Anchorage, AK 99501 MEMO ~ ~'®~~ ~:L25200060~:9914~~~6227~~~L556u' 0270 1 C~,2 °~ TERRIE L RUBBLE as-s~~zez 270 BP EXPLORATFON AK INC ~~ Mastercard Check" PO BOX 196612 MB 7-5 S, e~ ANCHORAGE, AK 99519-6612 GATE • • TRANSMITTAL LETTER CHECKLIST WELL NAME ~f~j~,/ ~~ ~ ~~ c.+- --C-r G ~.,~ PTD# ~~' -~~~~ Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. API No. 50- - - API number are , between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of welly until after (Company NameZhas designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company NameZmust contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1/25!06 C:\jody\transmittal checklist • • ^^ ~ a°'i n II O ~ N c Q ~. . ~ i ~ ~I Oi ~ ~ ~ _ N ~ ~ ~ ~ ~ I l N ' ~ I ~ CI w ~ . C E O ~ I ~ ~ ~ I I N ~ a i ~.. I ~~ ~, ~ ~ ~ '~ ~ ~ ~' ~ I II ~ !I I I I j mi = O ~ ~ ~i - i F- ; ZI ~i m ~ ' ~ ~ Wj ~ O ' N o'. ~ ~ ~ ~ ~ ~ ~ a ~~ ~ ~ w'i m ~ ~ ui o ~ ui. o. °o ~ I N ~ .0.~ ~, (O Y,. LLB, ~ N~ ,. I N o ~ ' m ~ ~I ~ a> Z 6 Q ao Z~ a~ x ~ ~ ! I W : N~ z I all I >. ; '~ I I o. i '~, '' N: N. N' N' N~ N~ tlD N~ N~ N.. N. N. N, N. N, N N~ N' N' N~ N, ~ N. N. N, N. N, Q. Q ~ II' ~ Q a, ' a, Q, Q ~ N, N~ Q, N. N. } Z N N' N, N, } ?. N~ ~ N. N, fq~ N' N, N, a, N:. N.. N. N, d, ~ Z ~ ~ ~ >- Y; i O O, Q, Z Z Z a, a, Q; a, z Z Z z I n ~ ~ >-, >-, }, } >-, Y• ~, ~ >-, >•, ~ Z, Z, Z; Z. Z Z Z } , , , , , , , ' ' , , ' I a LL~ ~ C ~ ~ ~ ~~ c ~ E. I 3 I m ~ ~, I c i, , I ~: : O. o, I : - v: T ' o v III ~. a~, v 3 O ~' «. ~ 3 c o I ~ , , O, ~ rv c' o I ~ ~ ~ I ~, o I O; ~ O`, ~ ~ ~ c' ~ ~ ~ ~ j. ~ C: O~ N~ ~ ~: ~ : a m. ~ ~~ ~ ~~ ~ ~ ~1 7~ N~ I ~ • ao m a ~_ ~- ~ ~ ~ v ~ a: m ~ o m~ ~, a~ i ,tS' ° ~. N m c ~ ~ ~ Q N: ~ , a >. ~ _ ~ . ~~ ~ E a o ~~ ~ 7~ 3 + ~ ?' m M~ O !~ N N C _ m C N 3 p N, }'.- Q ~ ~ .. ~ C ~ c O' C N 3 ' .0 ~0 , i U O. C ~, 7 ~~ ' . N O °; N a ~. . a y 4 `~ ° ~' ~, a 4- ~' N N. 3~ N, I N I Ln '~ U. ~ N _ t ~ . .. N m T ~ ~ N m 7• ?~~ O N N. N' ~ ~ ~~ C Of t ~, ~ C ~ T 7 O. ~ 7 tl), N ~ zl ~ a O' ~ ~' '~ N C ~ m ~ ~ ~ ~~ U m: ~ j ~ d ~ ~ N ~ N~ C. ~ O ~ O O. ~ ~ ~ ~ ~ -~ 'O. ' ~ . > ~ C, C ~ ~, ~, N, ' N O, m. C C, ' _ N, ~ ° ~,,. c ~ ~ ~ °~ C w ~~ C: G1 .+~"~f O1 ~ N ~ °' ti ; Z ~ '' D: : v° o o ,~ ~ c ~ o a v o m~ N o c r 3 o o >; o' rn c~ U' .Q ~ `° a d. ~ o g a; a c m Q 3! o, m ~ N ~ ~ >' m ~' Y °' I ~~g; ~ ~ o' ~ ~~~ ~' >;o>> °v m a~ ' m c~j :Y; ~ o~ ~~ , ~ E ~ `-° 3 a $ ~ ~ I I 0 3 I a ¢~ _ a~ ~ a c c ° ~ m c r n o o a~ m' w w n cc m Y, ° = ~ a' m' o c a :? d' m, =: a~ 4 a rn ~ t N o ~ o- 3' o' 0 3. ~ c > ~ m m `~ ° m' ~ in; m °` • ' m m' a~ °' m 3 •3 aa a N i 'y I a; N' ; c 3 m ~ N, ~ o o o. °~ a ~ ~ ~ ~ N o 3 _ , :? m a~ o Z o O' a Q a' c m ~ a c :,-- a =o, m o i. . a~ >~ ~' °- aai aai °' m' ~ o .. c> ~ a o' i o' m o , o° °' c ~ v o d : : y o a s N' a' £' ~ m E ~ , m °7 m o r ~: a N ° c H ~' a m' v' m m' ~ ~ y ~' °' ° a ~' ~ ~' ~ a °' N a;; '~ a uj _ N -d m E; ~ ~ ' ; ` 0, N ~ ° ' c ° c ~ ~ ~I ~, m m. ~ o o ~ ~ ~ v ~ q N uNi a ~ ~ o, I rn a m iu m '°' os m of 3 o ~ u i a' ~ , o ~ N O'. ~~ ~ N ~~ ~. a a N. N _ T ~ N, N N, 3.. C a "a' CI I ` ~ a' • N O' y. c, ~ > N C. m ~ 6 a L ~ p,. U ° ' U' I N 9 d~ ?. a O I f ~ ~ IL J a m' Q -~ ~ a' -O: V• •-~ ~~ ~. a;. a~ ~;~ m~ ~~ a, ~~ c. m. ~, .° ~ o..c~ o c ~ • ~ ~ N. ~~ c. c~ m : -, m ~. aNi' .m... t ' N' ~ N C U• °' aNi: m~ o~ ~' ~ ~ °v' ~~ ~ 6 c• ' '. C ~' ~ ~ ~~ ~" ' W m w' c 3' ~ ~ v ~ °~' 3 o o v ~ ~. ~' ~ a i.~' ~ o o. - v m _ a m a m °~ i o- ~ a~ c i ° ~ ~ ~ a I ~ (n ' Qy o' o o ?~ m > m o o ° °~' > ~ ° > 3 rn . ° m u ~ ~ ~ m 3' a d > N m :. . ' i a ' m ~ c J m! E , ~ a = - - ~ a i, m. m ~ ~ c -. 3 , I c, ~: i- ; ' °~ H; F- • ~; ~ , , ~ ~ o. o = ' n v 'i ~ ;a ~ T N: a c ° °~ °~ ° v. N (n J ~ ~ ~ ~ Q. 4 m, a~ m °, - a O O a U ~ ¢ , . U, I o: °. ~ U cn a U ¢ g ~ m, U, U, U' a, m a, v. O: O t, a ¢, ~, o m m U, ~, a~ a~ N ~, a m m m, o, o, cn cn, U, ~ ~ , , : , , , , , , , , , . ~ , W a ._.... O N M d' ~ f0 1~ W ~ N M V M O O ~ ~ r' ~ ~ ~ f0 CO O O ~ ~ N P -- ~ N M N N N ~--- a~ N _N f0 I~ CO 01 O ~- N N N _N N M M _M M~ ~ M M M! MT O n O O M M M M ~. ___ ____.,__, ~ U. - ----- ---_. ----- -O --- --- O ,. (O i C G C r+ N ! m N ~ m `. ~. N O ~ ~ ~ ~ O N '', ~~ W - o N ~ c ' • u'> I ~ ^ LL.. ~ J N Y N i L li d ~' ~ I J it ~ ~ U a ,~ , ~ a s C9 Q I ~ ~ a U o Q, a i ~ a s a ~ w` , a~ I ~ ~ a~ I V ~\ ~` 1~~\ J .N. m m "~,i c /, 0 _V .N ~~ ~ ~'~\ a~ 0 U N ~ `~ O c .~ 'm c w m m d U C O_ O N N 0 U • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ~. • M 1502BP62006182006SSN.txt Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Sep 25 10:21:49 2007 Reel Header Service name .............LISTPE Date . ...................07/09/25 Ori in ...................STS Ree~ Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Tape Header Service name .............LISTPE Date . ...................07/09/25 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Physical EoF Comment Record TAPE HEADER Prudhoe Bay unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: Library. scientific Technical services Library. scientific Technical services 15-026PB2 500292069772 BP Exploration Alaska, Inc. Sperry Drilling Services 25-SEP-07 MWD RUN 1 MWD RUN 2 MWD RUN 3 Mw0004429508 Mw0004429508 Mw0004429508 B. TRANI B.TRANI B. TRANI C. CLEMENS C. CLEMENS C. CLEMENS MWD RUN 4 Mw0004429508 B.TRANI C. CLEMENS 22 11N 14E 1441 285 Page 1 ~o~-a ~a ~1s561 t M 1502BP6200618200655N.txt ELEVATION (FT FROM MSL O) KELLY BUSHING: 66.50 DERRICK FLOOR: GROUND LEVEL: 32.90 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 8794.0 2ND STRING 6.125 7.000 10010.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE IS AN INADVERTENT SIDETRACK, RESULTING FROM A REAL-TIME MAD PASS WHILE RIH FOR MWD RUN 4. IT EXITS 15-02B PB1 AT 10652'MD/8886'TVD. 4. MWD RUNS 1,2 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR), UTILIZING GEIGER-MUELLER TUBE DETECTORS. THE PURPOSE OF MWD RUN 1 WAS TO POSITION THE WHIPSTOCK, MILL THE WINDOW, AND DRILL A BIT OF RAT HOLE. 5. MWD RUNS 3,4 COMPRISED DIRECTIONAL, DGR, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUN 4 ALSO INCLUDED AT-BIT INCLINATION (ABI), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND AZIMUTHAL LITHO- DENSITY (ALD). 6. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED HOLE GAMMA RAY LOG RUN ON 4 MARCH 1982 IN THE 15-02 WELLBORE. THESE DIGITAL DATA WERE PROVIDED BY D. DORTCH (SAIC/BP) ON 8 AUGUST 2007. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. THE SHIFTED DATA ARE PDC FOR 15-02B PB2. 7. MWD RUNS 1-4 REPRESENT WELL 15-02B PB2 WITH API#: 50-029-20697-72. THIS wELL REACHED A TOTAL DEPTH (TD) OF 11083'MD/9162'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). Page 2 1502BP62o06182006SSN.txt SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. DENSLIDE = NON-ROTATED INTERVALS REFLECTING ALD SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" BIT MUD WEIGHT: 8.6 PPG MUD SALINITY: 3800-4800 PPM CHLORIDES FORMATION WATER SALINITY: 11500 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 8485.5 11013.0 ROP 8788.0 11077.0 RPX 9984.0 11020.0 RPD 9984.0 11020.0 RPS 9984.0 11020.0 FET 9984.0 11020.0 RPM 9984.0 11020.0 FONT 10506.5 10986.5 NCNT 10506.5 10986.5 NPHI 10506.5 10986.5 RHOB 10519.0 11001.5 PEF 10519.0 11001.5 DRHO 10519.0 11001.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED BASELINE DEPTH 8485.5 GR 8492. DEPTH) --- EQUIVALENT UNSHIFTED DEPTH --------- Page 3 • 8499.5 8508.0 8510.0 8523.5 8526.5 8539.5 8561.5 8572.5 8580.5 8594.5 8600.0 8610.5 8627.5 8635.0 8637.0 8639.5 8646.5 8653.5 8656.0 8658.0 8661.0 8667.5 8673.0 8676.5 8678.5 8687.0 8690.5 8693.0 8697.5 8701.5 8713.5 8718.0 8722.5 8727.0 8729.0 8733.5 8737.5 8741.0 8744.5 8748.5 8758.0 8764.0 8769.5 8775.0 8776.0 8778.0 8780.5 8785.0 8795.0 11077.0 8506.5 8514.0 8516.0 8530.5 8532.0 8546.5 8566.0 8578.0 8585.0 8599.5 8605.0 8614.0 8633.5 8640.5 8643.5 8646.0 8653.0 8659.5 8661.5 8663.0 8667.0 8672.5 8677.5 8681.0 8683.5 8691.5 8695.5 8698.5 8702.5 8706.5 8718.0 8724.5 8728.0 8730.0 8732.5 8738.0 8742.5 8747.5 8752.0 8755.0 8767.0 8772.0 8777.0 8780.0 8781.0 8783.5 8787.0 8791.0 8801.0 11083.0 15026PB2o061820065SN.txt MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MwD 1 8492.5 8820.0 MwD 2 8820.0 10010.0 MwD 3 10010.0 10652.0 $wD 4 10652.0 11083.0 REMARKS: MERGED MAIN PASS. Page 4 • 15026P62o06182006SSN.txt Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent. value.. ..................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CNTS 4 1 68 4 2 NCNT MWD CNTS 4 1 68 8 3 RHOB MWD G/CM 4 1 68 12 4 DRHO MWD G/CM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HOUR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8485.5 11077 9781.25 5184 8485.5 11077 FCNT MWD CNTS 364.19 1065.33 612.988 961 10506.5 10986.5 NCNT MWD CNTS 21888.7 37488.1 28209.3 961 10506.5 10986.5 RHOB MWD G/CM 2.069 3.041 2.42366 966 10519 11001.5 DRHO MWD G/CM -0.153 0.317 0.0288416 966 10519 11001.5 RPD MWD OHMM 1.23 2000 102.198 2073 9984 11020 RPM MWD OHMM 1.91 2000 69.0207 2073 9984 11020 RPS MWD OHMM 1.21 1120.3 35.9149 2073 9984 11020 RPX MWD OHMM 0.96 566.66 25.7204 2073 9984 11020 FET MWD HOUR 0.55 72.57 3.19235 2073 9984 11020 GR MWD API 13.48 527.7 113.139 5056 8485.5 11013 PEF MWD BARN 0.93 5.34 2.14153 966 10519 11001.5 ROP MWD FT/H 0.85 315.62 84.6599 4579 8788 11077 NPHI MwD Pu-S 14.19 33.93 23.953 961 10506.5 10986.5 First Reading For Entire File..........8485.5 Last Reading For Entire File...........11077 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Page 5 • Physical EOF 15026PB2o06182006SSN.txt File Header Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8492.5 $OP 8794.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): STOP DEPTH 8777.0 8820.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: header data for each bit run in separate files. 1 .5000 2 10-JUN-06 Insite 66.37 Memory 8820.0 8794.0 8820.0 .0 50.3 TOOL NUMBER 216262 8.500 8794.0 Fresh water Gel 10.10 48.0 9.1 600 .0 .000 .0 .000 110.0 .000 .0 .000 .0 Page 6 • MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 15026P620061820065SN.txt Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 L..~I Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 GR MWDO10 API 4 1 68 4 2 ROP MWDO10 FT/H 4 1 68 8 3 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 8492.5 8820 8656.25 656 8492.5 8820 GR MWDO10 API 47.83 151.84 97.3446 570 8492.5 8777 ROP MWDO10 FT/H 0.85 8.8 3.85566 53 8794 8820 First Reading For Entire File..........8492.5 Last Reading For Entire File...........8820 File Trailer Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/25 Maximum Physical Record..65535 File TyL~e ................L0 Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 comment Record FILE HEADER Page 7 15026P62o06182006SSN.txt FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8777.5 9973.5 ROP 8820.5 10010.0 LOG HEADER DATA DATE LOGGED: 12-JUN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10010.0 TOP LOG INTERVAL (FT): 8820.0 BOTTOM LOG INTERVAL (FT): 10010.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 31.8 MAXIMUM ANGLE: 35.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216262 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 8794.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 10.15 MUD VISCOSITY (S): 51.0 MUD PH: 8.9 MUD CHLORIDES (PPM): 600 FLUID LOSS (C3): 4.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 113.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Da ta Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Page 8 15026P62o06182006SSN.txt optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD020 API 4 1 68 4 2 ROP MWD020 FT/H 4 1 68 8 3 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 8777.5 10010 9393.75 2466 8777.5 10010 GR MWD020 API 66.03 402.07 158.422 2393 8777.5 9973.5 ROP MWD020 FT/H 1.51 315.62 94.7551 2380 8820.5 10010 First Reading For Entire File..........8777.5 Last Reading For Entire File...........10010 File Trailer Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/25 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLI6.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9974.0 10652.0 FET 9990.0 10652.0 RPx 9990.0 10652.0 RPD 9990.0 10652.0 RPS 9990.0 10652.0 Page 9 • 15026P62o06182006SSN.txt RPM 9990.0 10652.0 ROP 10010.5 10652.0 LOG HEADER DATA DATE LOGGED: 16-7uN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE sOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10652.0 TOP LOG INTERVAL (FT): 10010.0 BOTTOM LOG INTERVAL (FT): 10652.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 23.7 MAXIMUM ANGLE: 85.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 EWR4 Electromag Resis. 4 167218 S BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10010.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 8.45 MUD VISCOSITY (S): 46.0 MUD PH: 9,5 MUD CHLORIDES (PPM): 5000 FLUID LOSS (C3): 5.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.900 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.160 122.0 MUD FILTRATE AT MT: 1.300 72.0 MUD CAKE AT MT: 2.200 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL. STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Log~iny Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Page 10 1502BPB20061820065SN.txt Name Service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9974 10652 10313 1357 9974 10652 RPD MWD030 OHMM 1.23 2000 151.284 1325 9990 10652 RPM MWD030 OHMM 1.91 2000 99.5271 1325 9990 10652 RPS MWD030 OHMM 1.21 1120.3 47.9292 1325 9990 10652 RPX MWD030 OHMM 0.96 566.66 32.5427 1325 9990 10652 FET MWD030 HOUR 0.89 72.57 4.58709 1325 9990 10652 GR MWD030 API 13.48 527.7 51.8911 1357 9974 10652 ROP MWD030 FT/H 3.28 240.76 58.0074 1284 10010.5 10652 First Reading For Entire File..........9974 Last Reading For Entire File...........10652 File Trailer Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLIB.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FCNT 10512.5 10992.5 NCNT 10512.5 10992.5 Page 11 • 15026P62o0618200655N.txt NPHI 10512.5 10992.5 PEF 10525.0 11007.5 DRHO 10525.0 11007.5 RHOB 10525.0 11007.5 RPS 10652.5 11026.0 RPM 10652.5 11026.0 FET 10652.5 11026.0 GR 10652.5 11019.0 RPX 10652.5 11026.0 RoP 10652.5 11083.0 RPD 10652.5 11026.0 LOG HEADER DATA DATE LOGGED: 18-JUN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11083.0 TOP LOG INTERVAL (FT): 10652.0 BOTTOM LOG INTERVAL (FT): 11083.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 47.0 MAXIMUM ANGLE: 51.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 99 CTN COMP THERMAL NEUTRON 18446744073 70955 EWR4 Electromag Resis. 4 167218 ALD Azimuthal Litho-Dens 1050894 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10010.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 42.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 5200 FLUID LOSS (C3): 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.800 71.0 MUD AT MAX CIRCULATING TERMPERATURE: .000 .O MUD FILTRATE AT MT: .800 72.0 MUD CAKE AT MT: .880 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Page 12 15026PB2006182006SSN.txt Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loggin Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD040 CNTS 4 1 68 4 2 NCNT MWD040 CNTS 4 1 68 8 3 RHOB MWD040 G/CM 4 1 68 12 4 DRHO MWD040 G/CM 4 1 68 16 5 RPD MWD040 OHMM 4 1 68 20 6 RPM MWD040 OHMM 4 1 68 24 7 RPS MWD040 OHMM 4 1 68 28 8 RPX MWD040 OHMM 4 1 68 32 9 FET MWD040 HOUR 4 1 68 36 10 GR MWD040 API 4 1 68 40 11 PEF MWD040 BARN 4 1 68 44 12 ROP MWD040 FT/H 4 1 68 48 13 NPHI MWD040 Pu-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10512.5 11083 10797.8 1142 10512.5 11083 FCNT MWD040 CNTS 364.19 1065.33 612.988 961 10512.5 10992.5 NCNT MWD040 CNTS 21888.7 37488.1 28209.3 961 10512.5 10992.5 RHOS MWD040 G/CM 2.069 3.041 2.42366 966 10525 11007.5 DRHO MWD040 G/CM -0.153 0.317 0.0288416 966 10525 11007.5 RPD MWD040 OHMM 3.69 47.96 15.2475 748 10652.5 11026 RPM MWD040 OHMM 3.58 47.66 14.9822 748 10652.5 11026 RPS MWD040 OHMM 3.53 49.6 14.6328 748 10652.5 11026 RPX MWD040 OHMM 3.54 42.63 13.6353 748 10652.5 11026 FET MWD040 HOUR 0.55 0.99 0.721738 748 10652.5 11026 GR MWD040 API 18.25 444.73 91.1515 734 10652.5 11019 PEF MWD040 BARN 0.93 5.34 2.14153 966 10525 11007.5 ROP MWD040 FT/H 1$.07 158.43 101.455 862 10652.5 11083 NPHI MWD040 Pu-s 14.19 33.93 23.953 961 10512.5 10992.5 First Reading For Entire File..........10512 Last Reading For Entire File...........11083 File Trailer Service name... .......STSLIB.005 Service SUb Level~Name... version Number. ........1.0.0 Date of Generation.......07/09/25 Maximum Physical Record..65535 File TyL~e ................LO Next File Name...........STSLIB.006 Page 13 15026P62o06182006S5N.txt Physical EOF Tape Trailer Service name .............LISTPE Date . ...................07/09/25 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. scientific Technical services Reel Trailer Service name .............LISTPE Date . ...................07/09/25 Origin ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File scientific Technical services Page 14 f ~• • 15026P61o06162006SSN.txt Sperry-Sun Drillin Services LIS Scan Uti~ity $Revision: 3 $ LisLib $Revision: 4 $ Tue Sep 25 08:55:30 2007 Reel Header Service name .............LISTPE Date . ...................07/09/25 Ori9in ...................STs Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. scientific Technical services Tape Header Service name .............LISTPE Date . ...................07/09/25 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Prudhoe Bay unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 W-0004429508 B. TRANI C. CLEMENS SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD scientific Technical services 15-026P61 500292069771 BP Exploration Alaska Inc. Sperry Drilling Services 25-SEP-07 MWD RUN 2 MWD RUN 3 W-0004429508 W-0004429508 B.TRANI B. TRANI C. CLEMENS C. CLEMENS 22 11N 14E 1441 285 66.50 32.90 Page 1 aa(~ -O ~'c~ ~ t 53 ~ 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 15026P61o0616200655N.txt OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 8794.0 6.125 7.000 10010.0 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE EXITS 15-02 BY MEANS OF A WHIPSTOCK, THE TOP OF WHICH WAS AT 8794'MD/7341'TVD. 4. MWD RUNS 1 & 2 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR), UTILIZING GEIGER-MUELLER TUBE DETECTORS. THE PURPOSE OF MWD RUN 1 WAS TO POSITION THE WHIPSTOCK, MILL THE WINDOW, AND DRILL A BIT OF RAT HOLE. 5. MWD RUN 3 COMPRISED DIRECTIONAL, DGR, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), 6. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED HOLE GAMMA RAY LOG RUN ON 4 MARCH 1982 IN THE 15-02 WELLBORE. THESE DIGITAL DATA WERE PROVIDED BY D. DORTCH (SAIC/BP) ON 8 AUGUST 2007. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. THE SHIFTED DATA ARE PDC FOR 15-02B PB1. 7. MWD RUNS 1-3 REPRESENT WELL 15-02B PB1 WITH API#: 50-029-20697-71. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11036'MD/8994'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.000 Page 2 15026PB1o06162006SSN.txt Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR ROP RPX RPS RPM RPD FET 1 and clipped curves; all bit runs merged. .5000 START DEPTH 8485.5 8788.0 9984.0 9984.0 9984.0 9984.0 9984.0 STOP DEPTH 10964.5 11030.5 10973.0 10973.0 10973.0 10973.0 10973.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 8485.5 8492.5 8499.5 8506.5 8508.0 8514.0 8510.0 8516.0 8523.5 8530.5 8526.5 8532.0 8539.5 8546.5 8561.5 8566.0 8572.5 8578.0 8580.5 8585.0 8594.5 8599.5 8600.0 8605.0 8610.5 8614.0 8627.5 8633.5 8635.0 8640.5 8637.0 8643.5 8639.5 8646.0 8646.5 8653.0 8653.5 8659.5 8656.0 8661.5 8658.0 8663.0 8661.0 8667.0 8667.5 8672.5 8673.0 8677.5 8676.5 8681.0 8678.5 8683.5 8687.0 8691.5 8690.5 8695.5 8693.0 8698.5 8697.5 8702.5 8701.5 8706.5 8713.5 8718.0 8718.0 8724.5 8722.5 8728.0 8727.0 8730.0 8729.0 8732.5 8733.5 8738.0 8737.5 8742.5 8741.0 8747.5 8744.5 8752.0 Page 3 .r~ 15026P61o06162006SSN.txt 8748.5 8755.0 8758.0 8767.0 8764.0 8772.0 8769.5 8777.0 8775.0 8780.0 8776.0 8781.0 8778.0 8783.5 8780.5 8787.0 8785.0 8791.0 8795.0 8801.0 11030.0 11036.0 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 8492.5 8820.0 MwD 2 8820.0 10010.0 MwD 3 10010.0 11036.5 REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service Order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8485.5 11030.5 9758 5091 8485.5 11030.5 RPD MWD OHMM 1.23 2000 110.051 1979 9984 10973 RPM MWD OHMM 1.91 2000 74.9096 1979 9984 10973 RPS MWD OHMM 1.21 1120.3 39.2202 1979 9984 10973 RPX MWD OHMM 0.96 566.66 28.0734 1979 9984 10973 FET MWD HOUR 0.89 72.57 3.88945 1979 9984 10973 GR MWD API 13.48 527.7 108.705 4959 8485.5 10964.5 ROP MWD FT/H 0.85 315.62 75.0004 4486 8788 11030.5 First Reading For Entire File..........8485.5 Last Reading For Entire File...........11030.5 Page 4 t~ 1502BPB1o061620065SN.txt File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/25 Maximum Physical Record..65535 File TyPe ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8492.5 8777.0 ROP 8794.0 8820.0 LOG HEADER DATA DATE LOGGED: 10-JUN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8820.0 TOP LOG INTERVAL (FT): 8794.0 BOTTOM LOG INTERVAL (FT): 8820.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .O MAXIMUM ANGLE: 50.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216262 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 8794.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 10.10 MUD VISCOSITY (S): 48.0 Page 5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 1502BP61006162006SSN.txt MUD PH: 9.1 MUD CHLORIDES (PPM): 600 FLUID LOSS (C3): .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 .000 .0 .000 110.0 .000 .0 .000 .0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 GR MWDO10 API 4 1 68 4 2 ROP MWDO10 FT/H 4 1 68 8 3 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 8492.5 8820 8656.25 656 8492.5 8820 GR MWDO10 API 47.83 151.84 97.3446 570 8492.5 8777 ROP MWDO10 FT/H 0.85 8.8 3.85566 53 8794 8820 First Reading For Entire File..........8492.5 Last Reading For Entire File...........8820 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/25 Maximum Physical Record..65535 File Ty e ................Lo Next File Name...........STSLIB.003 Physical EOF Page 6 ~~ 15026P61o06162006SSN.txt File Header Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.002 comment Record FILE HEADER FILE NUMBER: 3 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8777.5 9973.5 ROP 8820.5 10010.0 LOG HEADER DATA DATE LOGGED: 12-JUN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10010.0 TOP LOG INTERVAL (FT): 8820.0 BOTTOM LOG INTERVAL (FT): 10010.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 31.8 MAXIMUM ANGLE: 35.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216262 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 8794.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 10.15 MUD VISCOSITY (S): 51.0 MUD PH: 8.9 MUD CHLORIDES (PPM): 600 FLUID LOSS (C3): 4.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 113.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): Page 7 ~~ TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 15026P61o06162006SSN.txt REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units......... .Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 GR MWD020 API 4 1 68 4 2 ROP MWD020 FT/H 4 1 68 8 3 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 8777.5 10010 9393.75 2466 8777.5 10010 GR MWD020 API 66.03 402.07 158.422 2393 8777.5 9973.5 ROP MWD020 FT/H 1.51 315.62 94.7551 2380 8820.5 10010 First Reading For Entire File..........8777.5 Last Reading For Entire File...........10010 File Trailer service name... .......STSl.i6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Page 8 ~~ 15026PB1006162006SSN.txt Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9974.0 10970.5 FET 9990.0 10979.0 RPM 9990.0 10979.0 RPS 9990.0 10979.0 RPX 9990.0 10979.0 RPD 9990.0 10979.0 ROP 10010.5 11036.5 LOG HEADER DATA DATE LOGGED: 16-JUN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11036.0 TOP LOG INTERVAL (FT): 10010.0 BOTTOM LOG INTERVAL (FT): 11036.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 23,7 MAXIMUM ANGLE: 85.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 EWR4 Electromag Resi s. 4 167218 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 8810.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 8.45 MUD VISCOSITY (S): 46.0 MUD PH: 9,5 MUD CHLORIDES (PPM): 5000 FLUID LOSS (C3): 5.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.900 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.160 122.0 MUD FILTRATE AT MT: 1.300 72.0 MUD CAKE AT MT: 2.200 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Page 9 1502BPB1O06162006SSN.txt Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loggin Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MwD030 OHMM 4 1 68 12 4 RPX MwD030 OHMM 4 1 68 16 5 FET MwD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MwD030 FT/H 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 9974 11036.5 10505.3 2126 9974 11036.5 RPD MWD030 OHMM 1.23 2000 110.051 1979 9990 10979 RPM MwD030 OHMM 1.91 2000 74.9096 1979 9990 10979 RPS MWD030 OHMM 1.21 1120.3 39.2202 1979 9990 10979 RPX MWD030 OHMM 0.96 566.66 28.0734 1979 9990 10979 FET MWD030 HOUR 0.89 72.57 3.88945 1979 9990 10979 GR MWD030 API 13.48 527.7 52.3372 1994 9974 10970.5 ROP MwD030 FT/H 1.5 275.62 53.9359 2053 10010.5 11036.5 First Reading For Entire File..........9974 Last Reading For Entire File...........11036 File Trailer Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/25 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................07/09/25 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library scientific Technical services Page 10 15026PB1o061620065SN.txt Reel Trailer Service name...... .....LISTPE gate . ...................07/09/25 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF Physical EOF End Of LIS File writing Library. scientific Technical services Page 11 • r 15-02b.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Sep 25 14:08:40 2007 Reel Header Service name .............LISTPE Date . ...................07/09/25 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS writing Library. Scientific Technical Services Tape Header Service name .............LISTPE Date . ...................07/09/25 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments ...............-..STS LIS writing Library. scientific Technical services Physical EOF Comment Record TAPE HEADER Prudhoe Bay unit MWD/MAD LOGS WELL NAME: 15-02B API NUMBER: 500292069702 OPERATOR: BP Exploration Alaska Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 25-SEP-07 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: MW0004429508 MW0004429508 MW0004429508 LOGGING ENGINEER: B. TRANI B. TRANI B. TRANI OPERATOR WITNESS: C. CLEMENS C. CLEMENS C. CLEMENS MWD RUN 5 MWD RUN 6 MAD RUN 6 JOB NUMBER: MW0004429508 MW0004429508 MW0004429508 LOGGING ENGINEER: B. TRANI B. TRANI B. TRANI OPERATOR WITNESS: R. KLEPZIG R. KLEPZIG R. KLEPZIG SURFACE LOCATION SECTION: 22 TOWNSHIP: 11N RANGE: 14E FNL: 1441 FSL: FEL: FWL: 285 Page 1 ~Olo~O~'a ~ ~S~15'9 15-02b.tapx ELEVATION (FT FROM MSL 0) KELLY BUSHING: 66.50 DERRICK FLOOR: GROUND LEVEL: 32.90 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 8794.0 2ND STRING 6.125 7.000 10010.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE IS AN OPENHOLE SIDETRACK, EXITING 15-026 PB1 AT 10562'MD/ 8826'TVD. 4. MWD RUNS 1,2 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR), UTILIZING GEIGER-MUELLER TUBE DETECTORS. THE PURPOSE OF MWD RUN 1 WAS TO POSITION THE WHIPSTOCK, MILL THE WINDOW, AND DRILL A BIT OF RAT HOLE. 5. MWD RUNS 3,5,6 COMPRISED DIRECTIONAL, DGR, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUN 6 ALSO INCLUDED AT-BIT INCLINATION (ABI), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND AZIMUTHAL LITHO- DENSITY (ALD). UPHOLE MAD POROSITY DATA ACQUIRED WHILE POOH AFTER REACHING FINAL TD WERE MERGED WITH RUN 6 MWD DATA. RUN 6 MAD EWR DATA ARE INCLUDED AS A SEPARATE PRESENTATION. 6. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED HOLE GAMMA RAY LOG RUN ON 4 MARCH 1982 IN THE 15-02 WELLBORE. THESE DIGITAL DATA WERE PROVIDED BY D. DORTCH (SAIC/BP) ON 8 AUGUST 2007. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. MAD DATA WERE CORRECTED TO MWD DATA PRIOR TO SHIFTING. THE SHIFTED DATA ARE PDC FOR 15-026 PB2. 7. MWD RUNS 1-3,5,6 REPRESENT WELL 15-02B WITH API#: 50-029-20697-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12845'MD/8940'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). Page 2 15-02b.tapx SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP), TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. DENSLIDE = NON-ROTATED INTERVALS REFLECTING ALD SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" BIT MUD WEIGHT: 8.6 PPG MUD SALINITY: 3800-4800 PPM CHLORIDES FORMATION WATER SALINITY: 11500 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 8485.5 12774.5 ROP 8788.0 12839.0 RPX 9947.0 12781.5 FET 9947.0 12781.5 RPM 9947.0 12781.5 RPS 9947.0 12781.5 RPD 9947.0 12781.5 NCNT 10107.0 12748.0 FONT 10107.0 12748.0 NPHI 10107.0 12748.0 RHOB 10121.5 12763.0 PEF 10121.5 12763.0 RHO 10121.5 12763.0 $ Page 3 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED 15-02b.tapx r DEPTH) --- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 8485.5 8492.5 8499.5 8506.5 8508.0 8514.0 8510.0 8516.0 8523.5 8530.5 8526.5 8532.0 8539.5 8546.5 8561.5 8566.0 8572.5 8578.0 8580.5 8585.0 8594.5 8599.5 8600.0 8605.0 8610.5 8614.0 8627.5 8633.5 8635.0 8640.5 8637.0 8643.5 8639.5 8646.0 8646.5 8653.0 8653.5 8659.5 8656.0 8661.5 8658.0 8663.0 8661.0 8667.0 8667.5 8672.5 8673.0 8677.5 8676.5 8681.0 8678.5 8683.5 8687.0 8691.5 8690.5 8695.5 8693.0 8698.5 8697.5 8702.5 8701.5 8706.5 8713.5 8718.0 5718.0 8724.5 8722.5 8728.0 8727.0 8730.0 8729.0 8732.5 8733.5 8738.0 8737.5 8742.5 8741.0 8747.5 8744.5 8752.0 8748.5 8755.0 8758.0 8767.0 8764.0 8772.0 8769.5 8777.0 8775.0 8780.0 8776.0 8781.0 8778.0 8783.5 8780.5 8787.0 8785.0 8791.0 8795.0 8801.0 12839.0 12845.0 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MwD 1 8492.5 MwD 2 8820.0 MwD 3 10010.0 Page MERGE BASE 8820.0 10010.0 10562.0 4 MWD 5 MWD 6 REMARKS: MERGED MAIN PASS. 15-02b.tapx 10562.5 11052.0 11052.0 12845.0 Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Di rection .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CNTS 4 1 68 4 2 NCNT MWD CNTS 4 1 68 8 3 RHOB MWD G/CM 4 1 68 12 4 DRHO MWD G/CM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HOUR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8485.5 12839 10662.3 8708 8485.5 12839 FCNT MWD CNTS 284.07 3123.32 666.297 5283 10107 12748 NCNT MWD CNTS 20413.7 50220.6 29230.8 5283 10107 12748 RHOB MWD G/CM 2.081 3.136 2.40735 5284 10121.5 12763 DRHO MWD G/CM -0.3 0.482 0.0453081 5284 10121.5 12763 RPD MWD OHMM 1.23 2000 76.91 5670 9947 12781.5 RPM MWD OHMM 0.15 2000 45.7366 5638 9947 12781.5 RPS MWD OHMM 1.21 1120.3 27.6832 5670 9947 12781.5 RPX MWD OHMM 0.96 566.66 22.0612 5670 9947 12781.5 FET MWD HOUR 0.37 96.15 3.38318 5670 9947 12781.5 GR MWD API 13.48 527.7 90.0759 8579 8485.5 12774.5 PEF MWD BARN 0.73 7.92 2.15239 5284 10121.5 12763 ROP MWD FT/H 0.52 861.97 98.3264 8103 8788 12839 NPHI MWD Pu-5 5.47 40.29 23.1487 5283 10107 12748 First Reading For Entire File..........8485.5 Last Reading For Entire File...........12839 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number...........1.0.0 Page 5 15-02b.tapx Date of Generation.......07/09/25 Maximum Physical Record..65535 File TyL~e ................LO Next File Name...........STSLIB.002 Physical EoF File Header Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LI6.001 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MAD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR FET RPD RPS RPM R PX RAT MERGED DATA SOURCE PBU TOOL CODE MWD 2 clipped curves; all MAD runs merged using earliest passes. .5000 START DEPTH STOP DEPTH 10132.5 11089.5 10140.0 11091.5 10140.0 11091.5 10140.0 11091.5 10140.0 11091.5 10140.0 11091.5 10197.5 11148.0 MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE 6 1 10113.0 12845.0 REMARKS: MERGED MAD PASS. Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 RPD MAD OHMM 4 1 RPM MAD OHMM 4 1 RPS MAD OHMM 4 1 RPX MAD OHMM 4 1 FET MAD HOUR 4 1 Rep Code offset channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 Page 6 ~ ~ 15-02b.tapx GR MAD API 4 1 68 24 7 RAT MAD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10132.5 11148 10640.3 2032 10132.5 11148 RPD MAD OHMM 7.3 139.87 35.6295 1904 10140 11091.5 RPM MAD OHMM 7.02 111.32 29.8793 1904 10140 11091.5 RPS MAD OHMM 6.98 78.59 22.919 1904 10140 11091.5 RPX MAD OHMM 5.74 58.45 18.3056 1904 10140 11091.5 FET MAD HOUR 40.34 193.96 122.118 1904 10140 11091.5 GR MAD API 11.82 420.66 46.8047 1915 10132.5 11089.5 RAT MAD FT/H 0.14 584.12 155.467 1902 10197.5 11148 First Reading For Entire File..........10132.5 Last Reading For Entire File...........11148 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......5TSL26.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/25 Maximum Physical Record..65535 File Type.. ............LO Previous File Name.......STSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8492.5 8777.0 ROP 8794.0 8820.0 LOG HEADER DATA DATE LOGGED; 10-JUN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory Page 7 ~ r 15-02b.tapx TD DRILLER (FT): 8820.0 TOP LOG INTERVAL (FT): 8794.0 BOTTOM LOG INTERVAL (FT): 8820.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: 50.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216262 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 8794.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 10.10 MUD VISCOSITY (S): 48.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 600 FLUID LOSS (C3): 5.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 110.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 GR MWDO10 API 4 1 68 4 2 ROP MWDO10 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8492.5 8820 8656.25 656 8492.5 8820 Page 8 15-02b.tapx GR MWDO10 API 47.83 151.84 97.3446 ROP MWDO10 FT/H 0.85 8.8 3.85566 First Reading For Entire File..........8492.5 Last Reading For Entire File...........8820 File Trailer service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/25 Maximum Physical Record..65535 File Ty e ................Lo Next Fie Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLI6.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8777.5 $OP 8820.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY 570 8492.5 8777 53 8794 8820 header data for each bit run in separate files. 2 .5000 4 STOP DEPTH 9973.5 10010.0 12-7UN-06 Insite 66.37 Memory 10010.0 8820.0 10010.0 31.8 35.7 TOOL NUMBER 216262 Page 9 15-02b.tapx BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 8794.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 10.15 MUD VISCOSITY (S): 51.0 MUD PH: 8,9 MUD CHLORIDES (PPM): 600 FLUID LOSS (C3): 4.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 113.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ........,.0 Data specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 GR MwD020 API 4 1 68 4 2 RoP MwD020 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8777.5 10010 9393.75 2466 8777.5 10010 GR MWD020 API 66.03 402.07 158.422 2393 8777.5 9973.5 ROP MWD020 FT/H 1.51 315.62 94.7551 2380 8820.5 10010 First Reading For Entire File..........8777.5 Last Reading For Entire File...........10010 File Trailer Service name... .......STSLI6.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/25 Page 10 15-02b.tapx Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLI6.005• service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPx 9953.0 10562.0 RPD 9953.0 10562.0 FET 9953.0 10562.0 RPM 9953.0 10562.0 RPS 9953.0 10562.0 GR 9974.0 10562.0 ROP 10010.5 10562.0 S LOG HEADER DATA DATE LOGGED: 16-JUN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10562.0 TOP LOG INTERVAL (FT): 10010.0 BOTTOM LOG INTERVAL (FT): 10562.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 23.7 MAXIMUM ANGLE: 85.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 EWR4 Electromag Resis. 4 167218 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10010.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 8.45 Page 11 15-02b.tapx MUD VISCOSITY (S): 46.0 MUD PH: 9,5 MUD CHLORIDES (PPM): 5000 FLUID LOSS (C3): 5.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.900 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.160 122.0 MUD FILTRATE AT MT: 1.300 72.0 MUD CAKE AT MT: 2.200 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9953 10562 10257.5 1219 9953 10562 RPD MWD030 OHMM 1.23 2000 268.241 1219 9953 10562 RPM MWD030 OHMM 0.15 2000 126.045 1219 9953 10562 RPS MWD030 OHMM 1.21 1120.3 48.9456 1219 9953 10562 RPX MWD030 OHMM 0.96 566.66 32.8343 1219 9953 10562 FET MWD030 HOUR 0.89 72.57 8.92245 1219 9953 10562 GR MWD030 API 13.48 527.7 55.2573 1177 9974 10562 ROP MWD030 FT/H 3.75 240.76 57.8373 1104 10010.5 10562 First Reading For Entire File..........9953 Last Reading For Entire File...........10562 File Trailer Service name .............STSLI6.005 Page 12 • 15-02b.tapx Service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/25 Maximum Physical Record..65535 File TyC~e ................LO Next File Name...........STSLIB.006 Physical EOF File Header service name... .......STSLIB.006 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/25 Maximum Physical Record..65535 File Type. ...........LO Previous File~Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 10562.5 11001.5 ROP 10562.5 11052.0 FET 10562.5 11001.5 RPX 10562.5 11001.5 GR 10562.5 10994.0 RPD 10562.5 11001.5 PM 10562.5 11001.5 $ LOG HEADER DATA DATE LOGGED: 20-7UN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11052.0 TOP LOG INTERVAL (FT): 10562.0 BOTTOM LOG INTERVAL (FT): 11052.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 41.0 MAXIMUM ANGLE: 90.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 EWR4 Electromag Resis. 4 167218 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10010.0 Page 13 • 15-02b.tapx BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 Fresh water Gel 8.40 46.0 9.5 5000 6.0 1.900 73.0 1.110 130.0 1,320 73.0 2.250 73.0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MwD050 HOUR 4 1 68 20 6 GR MwD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10562.5 11052 10807.3 980 10562.5 11052 RPD MwD050 OHMM 7.37 55.1 24.367 879 10562.5 11001.5 RPM MwD050 OHMM 6.67 60.64 23.6045 879 10562.5 11001.5 RPS MWD050 OHMM 6.9 59.92 21.8278 879 10562.5 11001.5 RPX MWD050 OHMM 6.83 45.27 19.1169 879 10562.5 11001.5 FET MwD050 HOUR 0.59 96.15 1.65199 879 10562.5 11001.5 GR MwD050 API 14.68 142.81 48.9234 864 10562.5 10994 ROP MWD050 FT/H 1.84 861.97 102.019 980 10562.5 11052 First Reading For Entire File..........10562.5 Last Reading For Entire File...........11052 Page 14 15-02b.tapx File Trailer Service name... .......STSLI6.006 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EoF File Header Service name... .......STSLIB.007 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FCNT 10113.0 12754.0 NCNT 10113.0 12754.0 NPHI 10113.0 12754.0 PEF 10127.5 12769.0 DRHO 10127.5 12769.0 RHOB 10127.5 12769.0 GR 10994.5 12780.5 RPM 11002.0 12787.5 RPS 11002.0 12787.5 FET 11002.0 12787.5 RPD 11002.0 12787.5 RPx 11002.0 12787.5 ROP 11052.5 12845.0 LOG HEADER DATA DATE LOGGED: 24-JUN-06 SOFTWARE SURFACE SOFTWA RE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12845.0 TOP LOG INTERVAL (FT): 11052.0 BOTTOM LOG INTERVAL (FT): 12845.0 BIT ROTATING SPEE D (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.4 MAXIMUM ANGLE: 93.0 TOOL STRING (TOP TO BOTTOM) Page 15 VENDOR TOOL CODE DGR CTN EWR4 ALD 15-02b.tapx TOOL TYPE DUAL GAMMA RAY COMP THERMAL NEUTRON Electromag Resis. 4 .Azimuthal Litho-Dens BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 ~J TOOL NUMBER 135134 1844674407370955 167218 1050894 6.125 10010.0 Fresh water Gel 8.60 42.0 9.6 5300 5.5 1.800 71.0 .910 147.0 .900 71.0 .550 71.0 Name service order units Size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 FCNT MWD060 CNTS 4 1 68 4 2 NCNT MWD060 CNTS 4 1 68 8 3 RHOB MWD060 G/CM 4 1 68 12 4 DRHO MWD060 G/CM 4 1 68 16 5 RPD MWD060 OHMM 4 1 68 20 6 RPM MWD060 OHMM 4 1 68 24 7 RPS MWD060 OHMM 4 1 68 28 8 RPX MwD060 OHMM 4 1 68 32 9 FET MWD060 HOUR 4 1 68 36 10 GR MWD060 API 4 1 68 40 11 PEF MWD060 BARN 4 1 68 44 12 ROP MWD060 FT/H 4 1 68 48 13 NPHI MWD060 Pu-s 4 1 68 52 14 Page 16 15-02b.tapx First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10113 12845 11479 5465 10113 12845 FONT MWD060 CNTS 284.07 3123.32 666.297 5283 10113 12754 NCNT MWD060 CNTS 20413.7 50220.6 29230.8 5283 10113 12754 RHOB MWD060 G/CM 2.081 3.136 2.40735 5284 10127.5 12769 DRHO MWD060 G/CM -0.3 0.482 0.0453081 5284 10127.5 12769 RPD MWD060 OHMM 16.83 50.02 24.5451 3572 11002 12787.5 RPM MWD060 OHMM 15.36 52.05 23.7557 3572 11002 12787.5 RPS MWD060 OHMM 13.51 48.1 21.868 3572 11002 12787.5 RPX MWD060 OHMM 12.55 38.13 19.1093 3572 11002 12787.5 FET MWD060 HOUR 0.37 24.84 1.91883 3572 11002 12787.5 GR MWD060 API 20.32 127.36 64.5799 3573 10994.5 12780.5 PEF MWD060 BARN 0.73 7.92 2.15239 5284 10127.5 12769 ROP MWD060 FT/H 0.52 325.44 113.549 3586 11052.5 12845 NPHI MWD060 PU-S 5.47 40.29 23.1487 5283 10113 12754 First Reading For Entire File..........10113 Last Reading For Entire File...........12845 File Trailer Service name... .......STSLI6.007 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.008 Physical EOF File Header service name... .......STSLIB.008 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LI6.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MAD curves and log header data DEPTH INCREMENT: .5000 MAD RUN NUMBER: 6 MAD PA55 NUMBER: 1 FILE SUMMARY for each pass of each run in separate files, VENDOR TOOL CODE START DEPTH GR 10138.5 RPM 10146.0 RPS 10146.0 RPx 10146.0 RPD 10146.0 FET 10146.0 STOP DEPTH 11095.5 11097.5 11097.5 11097.5 11097.5 11097.5 Page 17 • 15-02b.tapx RAT 10203.5 11154.0 LOG HEADER DATA DATE LOGGED: 24-)UN-06 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TiME): Memory TD DRILLER (FT): 11154.0 TOP LOG INTERVAL (FT): 10203.5 BOTTOM LOG INTERVAL (FT): 11154.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .87,4 MAXIMUM ANGLE: 93.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 EWR4 Electromag Resis. 4 167218 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10010.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 42.0 MUD PH: 9.6 MUD CHLORIDES (PPM): 5300 FLUID LOSS (C3): 5.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.800 71.0 MUD AT MAX CIRCULATING TERMPERATURE: .910 147.0 MUD FILTRATE AT MT: .900 71.0 MUD CAKE AT MT: .550 71.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logyin Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Page 18 • 15-02b.tapx Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MAD061 OHMM 4 1 68 4 2 RPM MAD061 OHMM 4 1 68 8 3 RPS MAD061 OHMM 4 1 68 12 4 RPX MAD061 OHMM 4 1 68 16 5 FET MAD061 HOUR 4 1 68 20 6 GR MAD061 API 4 1 68 24 7 RAT MAD061 FT/H 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 10138.5 11154 10646.3 2032 10138.5 11154 RPD MAD061 OHMM 7.3 139.87 35.6295 1904 10146 11097.5 RPM MAD061 OHMM 7.02 111.32 29.8793 1904 10146 11097.5 RPS MAD061 OHMM 6.98 78.59 22.919 1904 10146 11097.5 RPX MAD061 OHMM 5.74 58.45 18.3056 1904 10146 11097.5 FET MAD061 HOUR 40.34 193.96 122.118 1904 10146 11097.5 GR MAD061 API 11.82 420.66 46.8047 1915 10138.5 11095.5 RAT MAD061 FT/H 0.14 584.12 155.467 1902 10203.5 11154 First Reading For Entire File..........10138.5 Last Reading For Entire File...........11154 File Trailer Service name... .......STSLIB.008 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/25 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.009 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................07/09/25 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS writing Library. Reel Trailer Service name .............LISTPE Date . ...................07/09/25 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. scientific Technical services scientific Technical Services Page 19 Phy5iCa1 EOF Physical EOF End Of LIS File 15-02b.tapx Page 20 •