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203-049
David Douglas Hilcorp Alaska, LLC Sr. GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: Date: 12/04/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL Well: PBU W-207PB1 PTD: 203-049 API: 50-029-23145-70-00 Definitive Directional Survey – 04/05/2003 Main Folder Contents: Please include current contact information if different from above. 203-049 T39803 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.12.04 10:42:36 -09'00' Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 02/09/2024 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 02/09/2024. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through 02/09/2024. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404 Report of Sundry Operations. If you have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Supervisor Hilcorp North Slope, LLC Digitally signed by Oliver Sternicki DN: cn=Oliver Sternicki, c=US, o=Hilcorp North Slope LLC, ou=PBU, email=oliver.sternicki@hilcorp.com Date: 2024.02.09 11:15:58 -09'00' Oliver Sternicki Hilcorp North Slope LLC. Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-off Report of Sundry Operations (10-404) 02/09/2024 Well Name PTD # API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date L-293 223020 500292374900 30 8/29/2023 S-09A 214097 500292077101 2 9/19/2023 S-102A 223058 500292297201 2 9/19/2023 S-105A 219032 500292297701 10 9/19/2023 S-109 202245 500292313500 7 9/19/2023 S-110B 213198 500292303002 35 9/19/2023 S-113B 202143 500292309402 10 9/19/2023 S-115 202230 500292313000 4 9/19/2023 S-116A 213139 500292318301 4 9/19/2023 S-117 203012 500292313700 3 9/19/2023 S-118 203200 500292318800 9 9/19/2023 S-122 205081 500292326500 5 9/19/2023 S-125 207083 500292336100 2 9/19/2023 S-126 207097 500292336300 3 9/19/2023 S-134 209083 500292341300 35 9/19/2023 S-200A 217125 500292284601 7 9/19/2023 S-202 219120 500292364700 13 9/19/2023 S-210 219057 500292363000 10 9/19/2023 S-213A 204213 500292299301 4 9/19/2023 S-215 202154 500292310700 3 9/19/2023 S-216 200197 500292298900 4 9/19/2023 S-41A 210101 500292264501 3 9/19/2023 W-16A 203100 500292204501 2 9/23/2023 W-17A 205122 500292185601 3 9/23/2023 Well Name PTD #API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date W-19B 210065 500292200602 8 9/23/2023 W-21A 201111 500292192901 8 9/23/2023 W-32A 202209 500292197001 4 9/23/2023 W-201 201051 500292300700 44 9/23/2023 W-202 210133 500292343400 6 9/23/2023 W-204 206158 500292333300 3 9/23/2023 W-205 203116 500292316500 3 9/23/2023 W-207 203049 500292314500 3 9/23/2023 W-211 202075 500292308000 8 9/23/2023 W-213 207051 500292335400 3 9/23/2023 W-214 207142 500292337300 10 9/23/2023 W-215 203131 500292317200 2 9/23/2023 W-223 211006 500292344000 7 9/23/2023 Z-69 212076 500292347100 2.0 27 1.5 10/24/2023 S-128 210159 500292343600 11 12/27/2023 S-135 213202 500292350800 16 12/27/2023 V-113 202216 500292312500 24 12/31/2023 V-114A 203185 500292317801 5 12/31/2023 V-122 206147 500292332800 5 12/31/2023 V-205 206180 500292333800 2 12/31/2023 V-207 208066 500292339000 8 12/31/2023 V-214 205134 500292327500 5 12/31/2023 V-215 207041 500292335100 2 12/31/2023 V-218 207040 500292335000 5 12/31/2023 V-224 208154 500292340000 16 12/31/2023 V-225 209118 500292341900 6 12/31/2023 V-01 204090 500292321000 3 1/1/2024 V-02 204077 500292320900 5 1/1/2024 V-04 206134 500292332200 5 1/1/2024 V-102 202033 500292307000 8 1/1/2024 V-104 202142 500292310300 5 1/1/2024 V-220 208020 500292338300 4 1/1/2024 W-207 203049 500292314500 3 9/23/2023 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, December 5, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC W-207 PRUDHOE BAY UN POL W-207 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/05/2023 W-207 50-029-23145-00-00 203-049-0 W SPT 4614 2030490 1500 1359 1360 1359 1359 254 267 263 260 4YRTST P Bob Noble 10/8/2023 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN POL W-207 Inspection Date: Tubing OA Packer Depth 292 2104 2064 2060IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN231009085610 BBL Pumped:1.3 BBL Returned:1.3 Tuesday, December 5, 2023 Page 1 of 1 MEMORANDUM State of Alaska Inspection Date: 10/10/2019 - Alaska Oil and Gas Conservation Commission To: Jim Regg '-� / �� ° l (of DATE: Monday, October 14, 2019 P.I. Supervisor ,. 7 SUBJECT: Mechanical Integrity Tests Initial 15 Min 30 Min 45 Min 60 Min BE Exploration (Alaska) Inc. W-207 Type Iuj W-207 FROM: Matt Herrera PRUDHOE BAY UN POL W-207 Petroleum Inspector 1066 ' Ste: Inspector Reviewed By: P.I. Supry J 193= NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN POL W-207 API Well Number 50-029-23145-00-00 Inspector Name: Matt Herrera Permit Number: 203-049-0 Inspection Date: 10/10/2019 - Insp Num: mi[MFH191010152844 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well W-207 Type Iuj W TVD 4614 "'Tubing 1066 ' 1066 1066 1066 - PTD 2030490 Type Test SPT Test psi 1500 IA 136 2002 1962 1953 - BBL Pumped: 1.4 - BBL Returned: L8 OA 218 243 - 232 - 225 - Interval _ 4YRTST P/F P Notes: IA pressure tested to 2000 PSI Per Operator c,UL 8(7e)l`l Odk was Sz (7Cz- fu�ta v4,a( Monday, October 14, 2019 Page I of I Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Sunday, September 1, 2019 8:08 AM To: Wallace, Chris D (CED) Cc: AK, GWO Projects Well Integrity, AK, GWO Well Integrity Well Information Subject: GC2 Injectors overdue for AOGCC MIT -IA Mr. Wallace, Injectors W-207 (PTD # 2030490) W-221 (PTD #2110290), W-220 (PTD #210260), W-223 (PTD #211060), R-06 (PTD #1981270), and W-219 (PTD #2101050) were due for 4 year AOGCC MIT-IAs at the end of August 2019. Due to the GC2 TAR the wells have been shut in and were not tested before the end of the month. GC2 is expected to be back up to full rate by the end of next week so BP is requesting to leave the above mentioned wells in Operable status and track them on the monthly compliance report until they are brought back online and pressure tested. Please advise if this is not acceptable, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 WELL LOG TRANSMITTAL # To: Alaska Oil and Gas Conservation Comm. February 11, 2019 Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: W-207 Run Date: 9/30/2018 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 W-207 Digital Data (LAS), Digital Log file�E® 1 CD Rom RECEIVED C C Y FEB 19 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com and Date: GANCPDC@USAANC.hou.xwh.BP.com I Signed: � (j d V / 20, 3049 30 36 7 • • Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Friday, September 04, 2015 8:59 PM To: Regg, James B (DOA);Wallace, Chris D (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay I Cc: AK, D&C Well Integrity Coordinator 71 7`'( Subject: August 2015 AOGCC MIT Forms Attachments: August 2015 MIT Forms.zip All, Please find the attached MIT forms for August 2015: Well: PTD#: L-103 2021390 P-10A 2150660 R-06 1981270 SCANNED y ' s f V-100 2010 0 VW-207 2030490 W-219 2101050 W-220 2101260 W-221 2110290 W-223 2110060 Thank you, Whitney Pettus €liernaie /'sirlcs) BP Alaska-Well Integrity Coordinator WIC Office: 907.659.5102 WIC Email: AKDCWeIllntegrityCoordinator@BP.com 1 0 • ` STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaaCd2alaska.gov; AOGCC.Insoectorsaalaska.gov- phoebe.brooks@alaska.aov chris.wallaceaalaska.aov OPERATOR: BP Exploration(Alaska),Inc. irk ifl//5 FIELD/UNIT/PAD: Prudhoe Bay/GPB/W l DATE: 08/03/15 OPERATOR REP: Kevin Parks AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well W-207 Type Inj. W " TVD - 4,614' Tubing 1,398 "1,399 1,399 - 1,399 Interval 4 P.T.D. 2030490 - Type test P Test psi - 1500 Casing 363 2,000 ' 1,966 1,960 P/F P Notes: 4yr MIT-IA to 2000 psi OA 193 240 , 197 ' 194 - Pumped 1.2 bbls ambient diesel,bled back 1.3 bbls Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MIT PBU W-207 08-03-2015.xms MEMORANDUM • State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Monday, September 26, 2011 TO: P Jim Supervisor T(77/11 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC W -207 FROM: Matt Herrera PRUDHOE BAY UN POL W -207 Petroleum Inspector Src: Inspector Reviewed By: - P.I. Supry . r -- NON- CONFIDENTIAL Comm Well Name: PRUDHOE BAY UN POL W -207 API Well Number: 50- 029 - 23145 -00 -00 Inspector Name: Matt Herrera Insp Num: mitMFHI10925115814 Permit Number: 203 -049 -0 Inspection Date: 9/23/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well W-207 - Type Inj. W ' TVD 4614 IA I 260 2000 - 1955 1950 P.T.D 2030490 - TypeTest SPT I Test psi � 1500 OA i 180 320 245 I 220 Interval 4YRTST p/F P _ Tubing 1280 1285 1280 1280 Notes: 1.7 BBL's to 011 IA.. Test pressure was 2000 psi Monday, September 26, 2011 Page 1 of 1 4 Cr 11/ = O CsiI- \ tO 0 § N (4 E 0 § `;) .§ � 2 . ) 50 !J@4A° , ;_g _ \m � /S° 8 o °g § ; 20 g� Qve . 2u / 2' d277\ 3k ) . ®2> ` \ in c ) fk r \ % , - - 2 , ° ) \ ?k d . } = p / ! v . — ( ° FRS§-,,,,. NNNO ))\\ § 7 C § 0 _ -J 0 = !o 1- 0 co U. Ui la Q�1- 0 2 k k=Ui z -I z LO o 4 E Kos m o §z flaw §»z a uk cek& map. § )§§w§wkm§n4 m3wEE2mmu■ z ■a®©°§� -° E * §§% 0 --;o% _,m0$ © §%■ COM...- 40U) -, 2§m§ 282 E mm § cog §IM w . . /a! • ; at ii _9�;a2'9,20 W33 'il\2 $s;65522§k E— ` ill ag a)) 2 Hit mao a m§!§ STATE OF ALASKA ALASKA APAND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other isi ,y FCC & ACID Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory p 203 -0490 3. Address: P.O. Box 196612 Stratigraphic0 Service 0 6. API Number: Anchorage, AK 99519 -6612 •= 50- 029 - 23145 -00 -00 8. Property Designation (Lease Number) : , 9. Well Name and Number: ADLO- 047451 ° W -207 10. Field /Pool(s): , PRUDHOE BAY FIELD / POLARIS POOL 11. Present Well Condition Summary: Total Depth measured 12380 feet Plugs (measured) None feet true vertical 5554.9 feet Junk (measured) None feet Effective Depth measured 12282 feet Packer (measured) 9421 11364 feet true vertical 5522.25 feet (true vertical) 4614 5224 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 20" 215.5# A53 29 - 109 29 - 109 Surface 9 -5/8" 40# L -80 28 - 4963 28 - 3198 5750 3090 Production 7" 26# L -80 36 - 12366 36 - 5550 7240 5410 Production R �c Liner *� H 1� 17 R � � Z� E Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 24 - 11400 24 - 5236 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker PRM Packer 9421 To 4614 4 -1/2" BKR S -3 PKR 11364 5224 RECEIVEC 12. Stimulation or cement squeeze summary: I\ pn R) r ij Intervals treated (measured): o & fi ns. jlnnnissron Treatment descriptions including volumes used and final pressure: ainQ 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 446 1,245 Subsequent to operation: 579 1,221 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development ❑ Service' El Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: „ Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ 1 WAG❑ 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: 310 -195 Contact Joe Lastufka Printed N- e J. Last Title Data Manager Signet re " 1 Phone 564 -4091 Date 4/18/2011 RBDMS APR 2 0 201-1-it, yZz . Form 10 -404 Revised 10/2010 Submit Original Only W -207 203 -049 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base W -207 4/16/03 PER 11,184. 11,194. 5,165.94 5,169.14 W -207 4/16/03 PER 11,762. 11,782. 5,352.39 5,358.78 W -207 4/16/03 PER 11,722. 11,742. 5,339.51 5,345.97 W -207 4/16/03 PER 11,646. 11,666. 5,314.81 5,321.29 W -207 4/16/03 PER 11,686. 11,706. 5,327.8 5,334.32 W -207 4/16/03 PER 11,442. 11,462. 5,249.23 5,255.68 W -207 4/16/03 PER 11,266. 11,276. 5,192.46 5,195.69 W -207 4/16/03 PER 11,218. 11,238. 5,176.89 5,183.39 W -207 4/16/03 PER 11,502. 11,522. 5,268.54 5,274.96 W -207 4/17/03 STO 9,421. 11,364. 4,613.85 5,224. W -207 7/14/03 STC 9,421. 11,364. 4,613.85 5,224. W -207 11/6/03 STO 9,421. 11,364. 4,613.85 5,224. • W -207 3/6/10 STC 9,421. 11,364. 4,613.85 5,224. 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 • • • W -207 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 4/2/2011;T/1/0=0/0/160 Temp= si [Fill Clean Out] Freeze protect F /L- Pumped 4 bbls neat meth down Injection F /L, blocked in lateral valves, Pumped 2 bbls neat meth up S- Riser throught Coil's return line to tank. * *Continued on 4-3-11** 3 4/2/201 1CTU 8 w/ 1.75" CT. Scope; FCO & Acid Wash. Rig up.. RIH w/ 2.80" JSN to perform fill CO * *job in progress ** 4/3/2011 CTU #8 w/ 1.75" CT ;Scope: Fill CO w/ KCI /hot diesel wash perfs /acidize to increase infection rate RIH jetting hot 2% KCI to wash tubing. Wash liner with same to 11500'. RIH dry to €11650' and saw no fill. Clean out to 11850' using hot KCI and used GeoVis. POOH ;chasing GeoVis to surface. RBIH w/ choke shut. Made two passes while pumping 61 i bbls of 160F diesel from 11400 to 11800' (planned 100 bbl of diesel not possible due I to LII Red pump failure). pump 30 bbls acid across perfs from 11432- 11800. 1 Overflush w/ 250 bbls kcl @ 3.7 bpm @ 1506 psi. Unable to establish program !injection rates due to whp. perform injectivity test @ .3 bpm @ 1290 psi, .7 bpm @ 1358 psi, 1.1 bpm @ 1402 psi. freeze protect well with 38 bbls 60/40 meth. perform weekly BOP test. RDMO to C- 27 * *'ob corn fete ** 4/3/2011 ;* *Continued from 4- 2 -11 ** *Safety drill* Rigged up to Coil tubing unit and pumped 61 bbls of 150* diesel. Coil on well on dep. Wing shut swab open ssv open casing !valves open to gauges Final Whp's = 1300/0/160 • • FLUIDS PUMPED BBLS 61 DIESEL 280 2% KCL 38 60/40 6 NEAT METH 385 TOTAL • TREE. = 4 - 1/16" GM/ • SAFETY S: VR PLUGS INSTALLED IN WELLHEAD = FMC VV-207 OUTLET 4.5" X 7" ANNULUS ON BOTH SIDES ACTUATOR = NA KB. ELEV = 52.40' BF. ELEV = 29.15' KOP = 400' 1019' H9 -5/8" TAM PORT COLLAR I Max Angle = 74° @ 3493' Datum MD = 10914' I 4241' H4 -1/2" HES X NIP, ID = 3.813" 1 Datum TV D = 5000' SS 9 -5/8" CSG, 40 #, L -80, D = 8.835" H 4963' I GAS LIFT MANDREL ST MD ND DEV TYPE VLV LATCH PORT DATE 1 4430 3034 72 KBG -2 DMY BK 0 07/14/03 Minimum ID = 3.308" @ 11258' 4 -1/2" HES SLEEVE (w/3.34" FN) I 9410' I—I4- 112 " HES X NIP, ID = 3.813" 1 ►-, 9421' I-1 X 4 -1/2" BKR PRM PROD FKR, ID = 3.875" I 9532' I--I4 - 1/2" HES X NIP, ID = 3.813" I — 9550' H7" MARKER w /RA TAG I — 10965' I—17" MARKER w /RA TAG I 11258' 4 - 1/2" AVA BPL PORTED NIP, ID = 3.70" l I IH 11258' I — SET AVA ISOLATION SLV IN NIP, ' ID = 3.30" (03/05/10) S ►�� 1 11364' I-17" X 4 -1/2" BKR S -3 PKR, ID = 3.813" I I 11387' N 4-1/2" HES RN NIP (3.688 ") 1 4-1 /2" TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958" I-1 11400' 1 ., w /NO GO, ID = 3.456" 11400' I - 112" WLEG, ID = 4.00" I PERFORATION SUMMARY REF LOG: LWD ON 04/11/03 ANGLE AT TOP PERF: 71 @ 11184' Note: Refer to Production DB for historical perf data SIZE SPF ZONE INTERVAL Opn /Sqz DATE 4 -1/2" 5 OBa 11184 - 11194 0 04/16/03 4 -1/2" 5 " 11218 - 11238 0 04/16/03 — 11522' I-17" MARKER w /RA TAG I 4 -1/2" 5 " 11266 - 11276 0 04/16/03 4 -1/2" 5 OBc 11442 - 11462 0 04/16/03 4 -1/2" 5 " 11502 - 11522 0 04/16/03 4 -1/2" 5 OBd 11646 - 11666 0 04/16/03 4 -1/2" 5 11686 - 11706 0 04/16/03 4 -1/2" 5 " 11722 - 11742 0 04/16/03 4 -1/2" 5 " 11762 - 11782 0 04/16/03 1 1 PBTD H 12281' IP 1♦Cift, 1►1/ 7" CSG, 26 #, L -80, .0383 bpf, ID = 6.276" I — I 12366' ■.14.1.4.1. ***.1.1. DATE REV BY COMMENTS DATE REV BY COMMENTS POLARIS UNIT 04/20103 JBM/TLH ORIGINAL COMPLETION 03/10/10 JCM/PJC SET ISOLATION SLV (03/05/10) WELL: W -207 07/14/03 JM/KAK GLV C/O PERMIT No: r 2030490 07/27/03 DAC/KK PORTED NIP CORRECTION API No: 50- 029 - 23145 -00 11/06/03 TW/TLP AVA CO- MINGLING SLV SEC 21, T11 N, R12E, 4285' NSL & 1186' WEL 03/13/08 TW /PJC PERF ZONE CORRECTIONS 10/17/09 RCT /PJC RN NIP ID CORRECTION BP Exploration (Alaska) • • ~~Q~C~ 0~ p~p~~Q /~..aa~~ao~.~. Josiah Igwe Petroleum Engineer ~~~~!~~,~~,~ ~_)!~' .`~ f'' ~~~J"`` BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 ~d3- 6 Re: Prudhoe Bay Field, Polaris Oil Pool, W-207 Sundry Number: 310-195 Dear Mr. Igwe: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this~~ day of June, 2010. Encl. STATE OF ALASKA ALASK~ AND GAS CONSERVATION COMMISSI~ APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ~ ,~ 6~ b ~~ ~ °~~ .~,q - 1. Type of Request: Abandon ^ Plug for Redrill ^ Pertorate New Pool ^ Repair Well ^ Change Approved Program ^ Suspend ^ Plug Perforations ^ Pertorate^ Pull Tubing ^ Time Extension ^ Operation Shutdown ^ Re-enter Susp. Well ^ Stimulate^~ Alter Casing ^ ^ Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ^ Exploratory ^ 203-0490 . 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-23145-00-00 . 7. If pertorating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ^ W-207 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-047451 , PRUDHOE BAY Field /POLARIS Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (meas ured): Junk (measured): 12380 5554.9 12282 5522.25 - NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 109 20" 215.5# A53 SURFACE 109 SURFACE 109 Surface 4935 9-5/8" 40# L-80 28 4963 28 3198 5750 3090 Intermediate 12340 7" 26# L-80 26 12336 26 5550 7240 5410 Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4-1/2" 12.6# L-80 SURFACE 11400 Packers and SSSV Tvoe: 7"X4-1/2" BKR PRM PROD PKR Packers and SSSV MD and ND (ftl: 9421 4614 7"X4-1/2" BKR S-3 PKR 11364 5224 12. Attachments: Description Summary of Proposal ^ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^/ . 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 6/30/2010 Oil ^ Gas ^ WDSPL ^ Plugged ^ 16. Verbal Approval: Date: WINJ ^~ GINJ ^ WAG ^ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Josiah Igwe Printed Name Josiah Igwe Title P E Signature ` •A ~' t f Phone Date -` ~ J'- 564-4753 6/23/2010 V ^~ . Prepared by Gary Preble 564-4944 COMMISSION USE ONLY Num itness Sund t ti f l N tif C i i th t C diti ber: 3 i ~ '~'' -1 / ry a represen ve may w ons o approva : y omm ss on so a a on o Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~ ~(~ ~ ~~~ t~UN 2 ~ 2010 Subsequent Form Required: ~U • YAK ~~BSt~ ~I! ~ r8~ ~UIi~. ~t1fTM'11~gS~q ~~f1f~l~?I'1({ APPROVED BY Approved b COMMISSIONER THE COMMISSION Date: ~ ~ 2 v. JUN 28 ~ - ~.L~~o ®~~ Form 10-403 evise 2/ 009 ~ Submit in Duplicate (JR1GI~iAL W-207 203-049 OCGC ATTA/'1-IMGNT L~ Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base W-207 4/16/03 PER 11,184. 11,194. 5,165.94 5,169.14 W-207 4/16/03 PER 11,762. 11,782. 5,352.39 5,358.78 W-207 4/16/03 PER 11,722. 11,742. 5,339.51 5,345.97 W-207 4/16/03 PER 11,686. 11,706. 5,327.8 5,334.32 W-207 4/16/03 PER 11,646. 11,666. 5,314.81 5,321.29 W-207 4/16/03 PER 11,442. 11,462. 5,249.23 5,255.68 W-207 4/16/03 PER 11,266. 11,276. 5,192.46 5,195.69 W-207 4/16/03 PER 11,218. 11,238. 5,176.89 5,183.39 W-207 4/16/03 PER 11,502. 11,522. 5,268.54 5,274.96 W-207 4/20/03 STO 9,421. 11,364. 4,613.85 5,224. W-207 8/11/03 STC 9,421. 11,364. 4,613.85 5,224. AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED 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 TREE= 4-1/16" CNV 1M~ELLHEAD~= FMC ACTUATOR = NA KB. ELEV = 52.40' BF. ELEV = 29.15' KOP = 400' Max Angle = 74° @ 3493' Datum MD = 10914' Datum TV D = 5000' SS 9-518" CSG, 40#, L-80, ID = 8.835" ( 4963' Minimum ID = 3.308" @ 11258' 4-1 /2" HES SLEEVE (w/3.34" FN) ~ 4-1/2" TBG, 12.6#, L-80, .0152 bpf, !D = 3.958" ~ PERFORATION SUMMARY REF LOG: LWD ON 04!11/03 ANGLE AT TOP PERF: 71 @ 11184' Note: Refer to Production DB for historical perf data SIZE SPF ZONE INTERVAL Opn/Sqz DATE 4-1/2" 5 OBa 11184 - 11194 O 04!16/03 4-1/2" 5 11218 - 11238 O 04/16/03 4-1/2" 5 11266 - 11276 O 04/16/03 4-1/2" 5 OBc 11442 - 11462 O 04/16/03 4-1 /2" 5 11502 - 11522 O 04/16/03 4-1/2" 5 OBd 11646 - 11666 O 04/16/03 4-1/2" 5 11686 - 11706 O 04/16/03 4-1i2" 5 11722 - 11742 O 04/16/03 4-1i2" 5 11762 - 11782 O 04/16/03 PBTD 7" CSG, 26#, L-80, .0383 bpf, ID = 6.276" DATE REV BY COMMENTS DATE REV BY COMMENTS 04!20(03 JBM/TL ORIGINAL COMPLETION 03110/10 JCM/PJC SET ISOLATION SLV (03/05/10) 07/14/03 JMlKAK GLV C(O 07/27/03 DAC/KK PORTED NIP CORRECTION 11/06/03 TW/TLP AVA CO-MINGLING SLV 03/13(08 TWiPJC PERF ZONE CORRECTIONS 10/17/09 RCT/PJC RN NIP ID CORRECTION POLARIS UNff WELL: W-207 PERMIT No: ~`L030490 API No: 50-029-23145-00 SEC 21, T11 N, R12E, 4285' NSL & 1186' WEL BP Exploration (Alaska) S TES: VR PLUGS INSTALLED IN W -~ ~ ~r OUTL O 4.5" X 7" ANNULUS ON BOTH SIDES • D1~-~9-5(8" TAM PORT COLLAR 241' 4-112" HES X NIP, ID = 3.813" GAS LIFT MANDREL MD TVD DEV TYPE VLV LATCH PORT DATE 430 3034 72 KBG-2 DMY BK 0 07114/0 ~4-1/2" HES X NIP, ID = 3.813" 7" X 4-1/2" BKR PRM PROD PKR, ID = 3.875" 4-112" HES X NIP, ID = 3.813" 7" MARKERw/RA TAG 7" MARKERw/RA TAG 11Z58~ ~- j4-1(2" AVA BPL PORTED NIP, ID = 3.70" 11258' SETAVA ISOLATION SLV IN NIP, ID - 3.30" (03/05/10) 11364' 7" X 4-1/2" BKR S-3 PKR, ID = 3.813" 11387' 4-1/2" HES RN NIP (3.688") w /NO GO, ID = 3.456" 11440' 4-1/2" WLEG, ID = 4.00" 7" MARKERwIRA TAG W-2071 • by ~~: ~~~ ~Z~ .:~~ i~~:~;,~ To: J. Bixby/C. Olsen GPB Well Ops Team Leaders From: Maggie Orlando Petroleum Engineer Josiah Igwe Wells Engineer Subject W-207i FCO & Acid wash / (PROF Job Sequence: AF~ APLWI'DWL07 Memorandum Date: June 11, 2010 AFE: APLWPDWL07-C Est. Cost: IOR: 300 1. S Drift and to TD. 2. C FCO & Acid Wash 3. E I-PROF/VVFL Current Status: Operable PWI Injection: 06/16/2010: 600 bpd, 1200 psi WHIP Max Deviation: 74 degrees @ 3,493' and Deviation at Perfs: 71 degrees @ 11184' and Last Tag: 07/11/2009: S S/L drift to 11,653' w/ 2.77" Cent Min. ID: 3.308" @ 11,258' md, 4-1/2" HES sleeve w/3.34 F/N Last Downhole Ops:S/Line set isolation sleeve at 11,248' slm on 03/06/2010 Latest H2S level: No data available but 20 ppm on offset wells SBHP/BHT 2,442 psi / 95 deg F @ 5000' TVD on 09/14/2007 History W-207i is a Polaris Schrader Bluff water injector with the OBa sand behind a straddle packer, and the OBc / OBd open below the tubing tail. An AVA commingling sleeve was replaced with an AVA blanking sleeve to isolate the OBa zone as it dominates injection. Slickline tagged schmoo build up to 11653' md, completely covering the OBd perfs. The OBd is a major sand in the offset producer W-205. Injection support into the OBd will therefore support production. Job Objective The objective of program is to uncover the OBd sands by jetting the schmoo build up back to surface. An acid wash will follow the FCO to increase injectivity into the OBd. A series of injection tests will confirm the injectivity into the lower zones. W-2071 • A~ APLWPDWL07 Contacts: Maggie Orlando Production Engineer Office /Cell: 564-4741/478-787-3168 Josiah Igwe Wells Engineer Office /Cell: 564-4753/590-0610 Slickline 1. Drift to maximum deviation with sample bailer. • Send sample to SLB lab for emulsion /sludge tests CT FCO w/ Acid wash Note: Before starting operation please ensure the followings; ^ Contact Pad Operator to shut-in injection. ^ Set up 2 flow back tanks on either side of the pad so the wind direction will not disrupt job during FCO ^ Connect SLB remote H2S monitor with Whaley extension to monitor H2S at the CT control unit ^ Freeze protect injection line as necessary. ^ 60/40 meth in the CT should freeze protect the well during the operation ^ Ensure all safety measures required for acid treatment are in place before proceeding with this job ^ Though there has not been reported case of H2S on this well but there is possibility that H2S might be present during flow back so extra caution should be taken. ^ Ensure that acid shower trailer is at the location and inspected 1. MU BHA with 2.25" JSN 2. RIH jetting 160 deg F extra slick 2% KCI at max rate while taking returns to the surface tanks • Ensure treating temperature for 2% KCI is not lower than 160 deg F. 3. Continue jetting hot Xs 2% KCI in hole with appropriate wt checks until close to slick line tagged depth 11,550'. • Ensure you are getting 1: ~0.8 returns while jetting 2 % KCI 4. Shut down pump and slowly dry tag fill. 5. PUH 20' off bottom and perform FCO as deep as possible using Geovis to carry solids to surface, uncover as deep as possible. 6. Once below 11,790' is reached, pump 10 bbls of Geovis and chase sweep to surface at 80%. 2 W-207i A~ APLWPDWL07 7. RBIH to 11,400' with the well shut in, jet hot diesel across the perforations while reciprocating between the intervals (11,400' - TD). 8. Jet estimated 100 bbls of hot diesel and PUH to 11,432' 9. With the nozzle at 11,432' pump 30 bbls of acid and per recipe below. 10. When acid is at the nozzle jet acid across the perfs (11,432' - 11,782') 11. When acid is out of the nozzle jet back across the perfs with hot 2% KCI to flush the tubing and over displace the acid. Pump at least 250 bbls of hot 2% KCI. 12. POOH 13. At surface perform injection test down production tubing with 2% KCI. Capture injection rates at 700 psi, 1,000 psi and 1,200 psi for 15 minutes each. Record results in the AWGRS summary. 14. Freeze protect tubing with 38 bbls 60/40 meth if the well cannot be POI immediately. 15. RDMO and secure well. 16. Notify Pad Operator to return well on injection +/-700 BWP. Acid Recipe: 30 bbls 12% MSR Acid MSR additive requirements: 0.2 % A261 Inhibitor Inhibitor A261 2.5 20.0 ppt L058 Iron Stablizer Iron Stabilizer L058 25 0.2 % W054 Non-Emulsifier Non-Emulsifier W054 2.5 0.2 % W060 Anti-sludge Anti- Sludge W060 2.5 W-207i E-Line IPROF/VVFL Logginq Procedure 1. Prior to starting (PROF, ensure the followings: • W-207i has been injecting for at least 3 days. • Establish injection rate at 700 bpd • Tie-in with Schlumberger USIT dated 4-16-03 below the TT. • NOTE: Sail angle of 70-72° from 3200' and to TD. Use rollers, and injection fluids to help pump down tool. 2. RU E-line GR / CCL/ temp /press /RST / Inline spinner /turbine spinner. Configure RST for WFL in down mode. 3. RIH to TD. Let well stabilize at above injection setting for 30 minutes before logging. 3 W-2071 ~ AI~ APLWPDWL07 4. Obtain up/down dynamic passes at 40fpm, 80 fpm, 120 fpm and 160 fpm from 11,300' to TD. 5. Check tie-in on way up, and obtain WFL stop counts from bottom to top. Stop depths are referenced to WFL tool sensor -tied-into tubing tally. • Ensure that two repeatable velocities are obtained between each perf set. • Adjust shot timing to obtain sharp WFL peaks without truncation of the signal. 11,300' MD 11,480' MD 11,580' MD 11,675' MD 11,715' MD 11,732' MD 11,752' MD TD 6. SI well. Double block the injection line if possible to ensure no injection. 7. Log up/down dynamic passes at 40 and 80 fpm from 11,300' - TD after 30 min shut in. 8. Log up/down dynamic passes at 120 and 160 fpm from 11,300' - TD after 90 min shut in. This will identify zonal X-flow, provide a cool back signature, and establish static- flow baseline passes. 9. POOH, RD, return the well to the pad operator to resume normal injection. Log Presentation: / Combine all data (IPROF &WFL) into one log. / Include WFL shot summary. With flow rate and %-of-total split for each stop. / Overlay the 40 fpm injection down temp pass with the 40 and 120 down SI passes / Label curves, jewellery, and perfs on all passes / Present all passes individually or in overlays / Present spinner up/down overlays of SI 80 & 120 fpm passes (or best passes) / Present the 40 fpm down SI GR to show actual WFL stop locations 4 r W-2071 ,~ N_E_l_LHEAD = 4CTUATOR _____hMG N_A <B. ELEV = 3F. ELEV = _ 52.40' 29.15' TOP= _ __400' _ _ Nax Angle = Datum MD _.... 74° @ 34_93' _-._~ 10914' ]atum TV D = 5000' SS 9-5(8" CSG, 40#, L-80, b = 8.835" ~- j 4963, Minimum ID = 3.308" @ 1125$' 4-112" HES SLEEVE (wl3.34" FN) 41/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 1-~ PERFORATION SUMMARY REF LOG: LWD ON 04I11f03 ANGLE AT TOP PERF: 71 @ 11184' Note: Refer to Production DB for historical pert data SIZE SPF ZONE (rITERVAL Opn/Sqz DATE 4-112" 5 OBa 111$4 - 11194 O 04/16103 4-1/2" 5 11218 - 11238 O 04!16/03 4-112" 5 11266 - 11276 O 04/16/03 4-112" 5 OBc 11442 - 11462 O 04116!03 4-112" 5 11502 - 11522 O 04/16/03 4-112" 5 OBd 11646 - 11666 O 04/16/03 4-112" 5 11686 - 11706 O 04!16/03 4-112" 5 11722 - 11742 O 04/16/03 4-112" 5 11762 - 11782 O 04!16103 PBTD 7" CSG, 26#, L-80, .0383 bpf, ID = 6.276" AF~ APLWI'DWL07 W ~/~ O ~ OUTLETS TO 4.5" X 7" ANNULUS ON BOTH SIDES 9-5/8" TAM PORT COLLAR 4-112" HES X NIP, ID = 3.813" GAS LIFT MANDREL 4-1/2" HES X NIP, ID = 3.813" 7" X 4-112" BKR PRM PROD PKR, 3D = 4-1/2" HES X N~', ID = 3.813" 7" MARKER w /RA TAG 7" MARKERw/RA TAG 1125$'......1-~ 4-1/2"AVA BPL PORTED NIP, ID = 3.70" '~ 125$' ET AVA ISOLATION SLV !N NIP, ~ ID = 3.30" (03/05!10} 11364' 7" X 4-112" BKR S-3 PKR, ID = 3.813" 11387' 4-112" HES RN NIP (3.688") wlNO GO, ID = 3.456" 11400' 4-112" WLEG, ID = 4.00" 7" MARKER w IRA TAG BATE REV BY COMMENTS DATE REV BY COMMENTS POLARIS UNTf 04120!03 JBMfTL ORIGINAL COMPLETION 03/10/10 JCIuVPJC SEt ISOLATION SLV (03!05110) WELL: W-207 07/14/03 JfvUKAK GLV CIO PERMIT No: 2030490 07/27!03 DAC/KK PORTED N~ CORRECTION API No: 50-029-23145.00 11/06!03 TWITLP AVA CO-MINGLING SLV SEC 21, T11 N, R12E, 4285' NSL & 1186' WEL 03/13/08 TW/PJC PERFZONECORRECTIONS 10717f0A RCTlP.I('. RN NIP If7 (:ORRFCTION RP Fx»I»rati»n (Atackal 5 ~~~[1~Uf~~l't~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 AITN: Beth Well Job # ~-; ~. !s ii.z ~, ~ '~ ~ ~. , . , ,. r : ~ ~,~:«~` ` ~s. Y Log Description Date oai2~ios NO. 5336 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 BL Color CD 14-12 AYTU-00048 USIT ~- ~ 07/26/09 1 1 L2-06 ANHY-00101 PRODUCTION PROFILE -- ~ ~ 07/23/09 1 1 03-20A AYKP-00034 CROSSFLOW CHECK C' 07/16/09 1 1 M-O6A AZCM-00034 PROOUCTION LOG '' - 07/13/09 1 1 P1-11 AYS4-00086 PRODUCTION PROFILE (p L 07/21/09 1 1 02-11A AYS4-00084 LDL J 07/20/09 1 1 W-212 B3SQ-00011 INJ PROFILE W/WFL ' - 07/20/09 1 1 W-215 AYKP-00036 INJ PROFILE W/RST-WFL p- 07/25/09 1 1 W-207 AYKP-00035 INJ PROFILE W/RST-WFL -6C L 07/24/09 1 1 H-29A AYQQ-00027 RST 'b 05/19/09 1 03-28 6146-00067 RST ~- " L.( 07/17l09 1 1 B-27A AXBD-00029 MCNL ~ O6/12/09 1 1 C-15A AWJI-00038 MCNL - O6/25/09 1 1 Q-04A B1JJ-00023 MCNL ~ ' 05/28/09 1 1 V-05 08AKA0024 OH MWD/LWD T 10/13/08 1 1 07-066 AWJI-00042 MCNL 07/21/09 1 1 02-33B 09AKA0149 OH MWD/LWD EDIT ~ O6/03/09 1 1 14-23A 09AKA0035 OH MWD/LWD EDIT 05/12/09 1 1 H-196 B2WY-00004 MCNL (REPLACEMEN~ - L 05/07/09 1 PLEASE ACKNOWLEDGE RECEIPT BY 51GNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 u i ~~ • • u '• ~ 03/01/2008 DO NOT PLACE ~~` ~~ *J. *~_ ~° ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFiche\CvrPgs_Inserts~4licrofilm Marker.doc MEMORANDUM • TO: Jim Regg `~ P.I. Supervisor FROM: Chuck SCheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commis DATE: Wednesday, October 03, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC W-207 PRliDHOE BAY L'N POL W-207 Src: Inspector NnN_(`(1NFTnF.NTIAL Reviewed By: P.I. Suprv Comm Well Name: PRUDHOE BAY UN POL W-207 API Well Number: so-029-23145-00-0o Inspector Name: Chuck Scheve mitCS07 1 00 3063040 Insp Num: Permit Number: 203-049-0 Inspection Date: 10/2/2007 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~, w-z07 '!TYPe Inj. ~' ~ TVD ~~ abat ~1 IA ~ o ~ z23o '~ ~ ~ zzlo ~ a~IO '~ ~~~ -----±- P.T. 203049D jTypeTeSt SPT ; 'l'est pSl ~~ 1500 °~ ~A, I 200 i 320 ~ r 27~ ~ 270 ~ Interval 4YRTST P/F ~ P__ Tubing ~'j Iooo ~ tooo I I000 ~~IOOO _I NOteS' Pretest pressures were observed and found stable. l G `~'(~ ~~ Q..u~ G~t ±Z. C~7tiitc~:. S~L~~Ii'E'y,~ ~>~~ N~~ J 7f1~7 Wednesday, October 03, 200 7 Page 1 of 1 Scldumberger L{~ ~/O 8° J~Þ 06/21/06 NO. 3862 Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: Alaska 011 & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Orion. Aurora, BoreaUs, Polaris Well Job# Log Description Date BL Color CO S-111 11216189 MEMORY /NJECTION PROFILE 04115/06 1 S-114A 10572082 RST UPFLOW WFL 03/01/03 1 V-105 10663005 INJECTION PROFILE 03112/04 1 E-103 10560276 TEMPERATURE WARMBACK 06/22/03 1 V-214 11162720 UBI 11/24105 1 V-213 11076450 INJECTION PROFILE 07/01/05 1 V.216 11076451 INJECTION PROFILE 07/02/05 1 V-221 11058523 INJECTION PROFILE 07/03/05 1 L-103 N/A INJECTION PROFILE 07/18/09 1 W-209 11076461 INJECTION PROFILE 08/20/05 1 W-207 10980589 INJECTION PROFILE 07/20/05 1 W-212 N/A INJECTION PROFILE 07/19/05 1 , e PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc, PetrolecMical Data Center LR2-1 900 E Benson Blvd, Anchorage AK 99508-4254 Date Delivered: C1Þ Sch/umberger-DCS 2525 Gambel! St. Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Received by: e RECEIVED JUN 2 3 2006 ~ Cit & Gas Cci'lS. Commission Anchorage Id- ~ -,. ~ ~ 02113/06 d-,t»" ot.tq r~b ò:, rI:u £ '1-; fß w g.Þl Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 NO. 3680 Company: ........... ,¿"mO). "'JÜiT~m¡s.S~Qn Schlumberger Schlurnberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Polaris Borealis Aurora Field: ~ CD Color BL Date 01/03/06 12/15/03 OS/28/05 01/01/06 11/03/03 12/15/03 04/04103 Log Description PERF/SSHP OH LDWG EDIT OF MWD/LWD USIT USIT OH LDWG EDIT OF MWD/LWD OH LDWG EDIT OF MWD/LWD OH LDWG EDIT OF MWD/LWD Job# 11057082 40009730 11058510 10987558 40009730 40009730 40008886 Wel 5-03 î91- ''fO V-1i4A(REVISED\ 5-111 L-123 _ Y-114A PSi .t}ð3-w..- Y-114A PS2 1l0;.L ~ W-207 PSi aÞ~-01~ ~tP.)- 185 Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth R.re',,' JJm.@O !tì ~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2 900 E Benson Blvd. Anchorage AK 99508-4254 ¿) I :;}~J D~ Date Delivered: ~ 8 2005 §cr~NNEC FEB 2 Schlumberger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well E-102 :.<.vi.....~~ E-102 J-.~} -I ~Ï¿, . V-105 .2. (¡ '1 - ¡ J l W-212 :lù-:2, - ..·iat W-207Jin·~ .. (,4~ 10708040 10672378 10687690 10679053 10703968 Job# SBHP SURVEY PPROF W/DEFT/GHOST INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE 08/30/05 NO. 3462 ~03 - 0 '+-0/ Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Midnight Sun Polaris Date BL Color CD 12/10103 05/01/08 06/26/04 \J¡ c:.. 01/28/04 .1.,..\ t c.... 01/26/04 l) ¡ c. Log Description PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: J ,~ .~~ \ ·~c t.d\l ~\I F L ,~!=' P (,I Ii' ? 0 n ~¡ ~-...;tto:t.:~\.:-=þ...- \o.,...~~,. l """"" ...dV --" Schlumberger-DCS 2525 Gambell St. Suite 400 Anchorage. AK 99503-2838 _ , ATTN Beth tJj / (' (')J! I Received by. ~.~ LJk{¡frvI -. I q M<J À.14-;- DATA SUBMITTAL COMPLIANCE REPORT 5/10/2005 Permit to Drill 2030490 Well Name/No. PRUDHOE BAY UN POL W-207 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23145-00-00 MD 12380 TVD 5555 Completion Date 4/19/2003 Completion Status 1WINJ Current Status 1WINJ GcO~ - ------._--- REQUIRED INFORMATION Mud Log No Samples No Directional surveYt y~ DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, DEN, NEU, PWD, USIT Well Log Information: (data taken from Logs Portion of Master Well Data Maint) Log/ Data Digital ~ed/Frmt Electr Dataset Number ~-' Name Directional Survey Log Log Scale Media Run No 1 Interval OH / Start Stop CH o 12380 Open Received 5/5/2003 Comments ./' ¡ED C y.- 12228 Neutron 3 4950 12275 Open 1 0/31/2003 LDWG Open hole Edit of Drilling & Measurement data ED C iff' 12228 Density 3 4950 12275 Open 1 0/31/2003 LDWG Open hole Edit of J Drilling & Measurement I ED data C "rr' 12228 I nd uction/Resistivity 1-3 108 12379 Open 1 0/31/2003 LDWG Openhole Edit of Drilling & Measurement data ¡ED C Pds 12228 Neutron 25 3 4950 12275 Open 10/31/2003 Vision Density Neutron -~/ ED C Pds 12228 Density 25 3 4950 12275 Open 1 0/31/2003 Vision Density Neutron .J=D C Pds 12228 I nd uction/Resistivity 25 1-3 108 12328 Open 1 0/31/2003 Vision Density Neutron ~ Neutron 25 Blu 3 4950 12275 Open 1 0/31/2003 See Vision Service Log, individual Log CULLED /og Density 25 Blu 3 4950 12275 Open 1 0/31/2003 See Vision Service Log, individual Log CULLED ¡JOg Induction/Resistivity 25 Blu 1-3 108 12328 Open 1 0/31/2003 See Vision Service Log, - I ~nt Evaluation individual Log CULLED I~ 5 Col 7450 11550 Case 12/22/2003 Ultra Sonic Imaging Tool, L___ Gamma Ray/CCL DATA SUBMITTAL COMPLIANCE REPORT 5/10/2005 Permit to Drill 2030490 Well Name/No. PRUDHOE BAY UN POL W-207 Operator BP EXPLORATION (ALASKA) INC æ: 10-0~-2~-O~~' J MD 12380.--'" TVD 5555 ",. Completion Date 4/19/2003 ..,/ Completion Status 1WINJ Well Cores/Samples Information: Name Interval Start Stop Received Sent ADDITIONAL INFORMATION Well Cored? . v ¡.(!) · Chips Received? . Y / N Daily History Received? Formation Tops Analysis Received? ~ Comments: Compliance Reviewed By: . ~ ~ Current Status 1WINJ Sample Set Number Comments ~ ~/N Date: UIC Y ~-" Å,l., ~ À(\O.1 - -- 12/15//03 Schlumberger NO. 3071 Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job# Log Description Field: Polaris Borealis Orion Date BL Color CD "-' 04/16/03 1 11/12/03 1- 1 )f),~( 11/15/03 2 11/17103 t 1 }d... ~ ¿ () W-207 ~()~-êf"'lq 10564457 USIT V-114APB1 tl_" )g.~ 10687655 CH EDIT US IT (PDCL) V -202 ("\., CSj T 10662969 SCMT V-114A a~----\ ~5 10662970 CH EDIT CBUSONIC GR -.---- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 REce'VED DEC 22 2003 Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 A TIN: Beth Date Delivered: Received b~-....é\'l"-t j~~ ~'--"'.... Álaska Oil & l."öS Lens. COmmtSStOn Anchor8ge l' Schlumberger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Well Job# 40008886 40008886 40008886 40008886 40008886 40008886 40008886 Log Description Date OH LDWG EDIT OF DRILLING & MEASUREMENT DATA MD VISION RESISTIVITY TVD VISION RESISTIVITY MD VISION DEN/NEUTRON TVD VISION DEN/NEUTRON MD VISION SERVICE TVD VISION SERVICE 04/11/03 04/11/03 04/11/03 04/11/03 04/11/03 04/11/03 04/11/03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: ~~~N\~ F~E:CEI\JED OCT 1.<1fì "',7- ""Z rIP;,} I V : .!-.....~,,""$O" J)~~f'l::;f~fi ü~-i & (32& (~GnB. Cornmisston þ,nc-horage 1 0/30/03 NO. 3008 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Polaris BL Color CD .~ }é)ry()~ 1 1 1 1 1 1 1 -'---- Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Beth Received~~~~~ ) MEMORANlIJM State t" )AI as ka Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich Commissioner DATE: September 12, 2003 SUBJECT: Mechanical Integrity Tests THRU: Jim Regg 17 011"-"1 ì:S BPX P.I. supervisorfVV1 :J(t:L. PBU W pad W-207i FROM: Lou Grimaldi Prudhoe Bay Field Petroleum Inspector NON- CONFIDENTIAL Packer Depth Pretest Well W-207 Type Inj. S T.V.D. 4613 Tubing 1680 P.T.D. 2030490 Type test P Test psi 1500 Casing 1870 Notes: Dropped pretest pressures to exhibit tubing integrity Well W-207 Type Inj. S TV.D. 4613 Tubing 1640 P.T.D. 2030490 Type test P Test psi 1500 Casing 1060 Notes: Same well, raised IA pressure to exhibit integrity. Type INJ. Fluid Codes Type Test F = FRESH WATER INJ. M= Annulus Monitoring G = GAS INJ. P= Standard Pressure Test S = SALT WATER INJ. R= Internal Radioactive Tracer Survey N = NOT INJECTING A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details M.I.T.ls performed: Attachments: Number of Failures: Initial 15 Min. 30 Min. 1670 1670 1670 Interval 0 / 1040 1060 1060 P/F f 1640 1640 1640 Interval 4 / 2220 2210 2200 P/F f Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) Total Time during tests: cc: Tom Maunder (A.O.G.C.C.) K-~ MIT report form 5/12/00 L.G. M IT PBU 09-12-03 LG 1.xls 9/15/2003 ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / W Pad 09/12/03 Joe Anders Lou Gramaldi í<qi q~g\<B Well W-207 Type Inj. S P.T.D. 2030490 Type test P Notes: Initial MITIA, new well Well Type Inj. P.T.D. Type test Notes: Well Type Inj. P.T.D. Type test Notes: Well Type Inj. P.T.D. Type test Notes: Well Type Inj. P.T.D. Type test Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting Packer Depth (TVD-ft.) Pretest Initial 15 Min. 30 Min. TVD 4,613' Tubing 1,640 1,640 1,640 1,640 Interva I v/ Test psi 1500 Casing 1,020 2,220 2,210 2,200 P/F P TVD Tubing Interva T est psi Casing P/F TVD Tubing Interva Test psi Casing P/F TVD Tubing Interva T est psi Casing P/F TVD Tubing Interva Test psi Casing P/F TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT PBU W-207 09-12-031.xls W-207 MIT Form ) ) pri)ZiJ3- 049 Subject: W-207 MIT Form Date: Fri, 12 Sep 2003 23:58:25 -0500 From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> To: "AOGCC Bob Fleckenstein (E-mail)..<Bob_Fleckenstein@admin.state.ak.us>. "AOGCC Field Inspectors (E-mail)..<AOGCC_Prudhoe_Bay@admin.state.ak.us>. (' .' ( ~ "AOGCC Jim Regg (E-mail)..<Jim_Regg@admin.state.ak.us>. r-~t1 1rsiò.? "AOGCC Winton Aubert (E-mail)..<Winton_Aubert@admin.state.ak.us> ( cc: "Engel, Harry R" <EngelHR@BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor@BP.com> Attached is the completed MIT form for W-207 - it passed. Please call if you have any questions. «MIT PBU W-207 09-12-03.xls» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: (907) 659-5102 Mobile: (907) 943-1154 Pager: (907) 659-5100, xl154 Email: NSUADWWellIntegrityEngineer@bp.com Name: ]\tIlT PBU 'vV-207 09-12-03.xls OMIT PBU W-207 09-12-03.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel) Encoding: base64 ",,,,,,.,,;...;,,..;,..,,,,:,.,,.,;;.,,¡,,.,,,,;..~,,.;,...;,,;,,.,,,¡:.,,,:,,,;",,,,,¡,,,,,,,,,,;,..¡:,,..,,,.,.,,..,,,.:',,,,,,,.,,:,,,,,¡,...,....:,,;,,..,,":"":""'''''''¡'';'':':''':'';''''¡''¡'''''''''''¡''''''''¡'''i.:.'.....":..;."...";........"",;.;,...,,..,,.;,.,: ,,,.;~....,,¡,,..¡¡,,¡"",",,,..,,,...,,.,,...;¡:.,:..;.,,¡...:.;.;."i¡,.¡i..";"¡~ 1 of 1 9/15/20039:41 AM ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised: 08/25/03, Put on Injection 'I. Status of Well Classification of Service Well o Oil 0 Gas 0 Suspended 0 Abandoned 1m Service Water Injection 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 203-049 3. Address 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23145-00 4. Location of well at surface 9. Unit or Lease Name 4285' NSL, 1186' WEL, SEC. 21, T11 N, R12E, UM X = 612049, Y = 5959261 Prudhoe Bay Unit At top of productive interval 1782' NSL, 2149' EWL, SEC. 23, T11 N, R12E, UM X = 620706, Y = 5956893 10. Well Number At total depth W 1475' NSL, 3244' EWL, SEC. 23, T11 N, R12E, UM X = 621806, Y = 5956604 -207i 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field I Polaris Pool KBE = 80.9' ADL 047451 (Undefined) 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 15. Water depth, if offshore 16. No. of Completions 4/2/2003 4/11/2003 4/19/2003 N/A MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 12380 5555 FT 12282 5522 FT 1m Yes 0 No (Nipple) 42411 MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, DEN, NEU, PWD, US IT 23. CASING SIZE 20" X 34" 9-5/8" WT. PER FT. 215.5# 40# 26# GRADE A53 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 109' 48" 28' 4963' 12-1/4" 26' 12366' 8-3/4" CEMENTING RECORD 260 sx Arctic Set (Approx.) 860 sx PF IL', 298 sx Class 'GI 610 sx Class 'G' AMOUNT PULLED 7" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 4-1/2" Gun Diameter, 5 spf MD TVD 111841 -111941 5166' - 51691 11218'-11238' 5177'-5183' 11266' - 11276' 5192' - 5196' 11442' - 11462' 5249' - 5256' 11502' - 11522' 5269' - 5275' 11646'-11666' 5315'-5321' 11686' - 11706' 5328' - 5334' 11722' - 11742' 5339' - 5346' 11762' - 11782' 5352' - 5359' 27. Date First Production August20,2003 Date of Test Hours Tested 25. SIZE 4-1/2", 12.6#, L-80 TUBING RECORD DEPTH SET (MD) 11400' PACKER SET (MD) 9421' & 11364' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 82 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Water Injection PRODUCTION FOR OIL-BBL TEST PERIOD GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO F-Iow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) No core samples were taken. '-'; ') Form 10-407 Rev. 07-01-80 ROOMS Bfl l\uG 2. \j~ \ G' N A L ~~ Submit In Duplicate , ) '" 29. Geologic Markers Marker Name Measured Depth Ugnu 6031' Ugnu M 9581' Schrader Bluff N 10369' Schrader Bluff 0 10982' OBa 11178' OBb 11314' OBc 11442' OBd 11640' OBe 11878' OBf 12030' Base Schrader Bluff 0 12189' 31 . List of Attachments: ) 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 3539' 4665' 4916' 5102' 5164' 5208' 5249' 5313' 5390' 5439' 5491' Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ~~ t{,/~~ Trtle Technical Assistant Date æ,z·O~ W-207i 203-049 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number / Drilling Engineer: Michael Triolo, 564-5774 Permit No. Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ORIGINAL J ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / W 07/21/03 Iveson Packer Depth (TVD-ft.) Pretest Initial 15 Min. 30 Min. Well W-207 Type Inj. S TVD 4,613' Tubing 0 50 50 0 P.T.D. 2030490 Type test P Test psi 1500 Casing 0 2,500 2,440 2,430 Notes: This is a pre-injection MITIA. The AOGCC witnessed MITIA will be performed once the well is POI. Well Type Inj. TVD Tubing P.T.D. Type test T est psi Casing Notes: Well Type Inj. rvD Tubing P.T.D. Type test T est psi Casing Notes: Well Type Inj. TVD Tubing P.T.D. Type test T est psi Casing Notes: Well Type Inj. TVD Tubing P.T.D. Type test T est psi Casing Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test MIT Report Form Revised: 06/19/02 2003-0721_MIT _PBU_W-207.xls Interva 0 P/F P Interva P/F I nterv a P/F I nterv a P/F Interva P/F INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ) 1. Status of Well o Oil 0 Gas 0 Suspended 0 Abandoned Ia Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 4285' NSL, 1186' WEL, SEC. 21, T11 N, R12E, UM At top of productive interval 1782' NSL, 2149' EWL, SEC. 23, T11 N, R12E, UM X = 620706, Y = 5956893 10. Well Number At total depth 1475' NSL, 3244' EWL, SEC. 23, T11N, R12E, UM X = 621806, Y = 5956604 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field I Polaris Pool KBE = 80.9' ADL 047451 (Undefined) 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 15. Water depth, if offshore 16. No. of Completions 4/2/2003 4/11/2003 4/19/2003 N/ A MSL One 17. Total Depth (MD+ TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 12380 5555 FT 12282 5522 FT Ia Yes 0 No (Nipple) 4241' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, G R, RES, DEN, NEU, PWD, USIT Classification of Service Well Water Injection 7. Permit Number 203-049 X = 612049, Y = 5959261 8. API Number 50- 029-23145-00 9. Unit or Lease Name Prudhoe Bay Unit W-207i 23. CASING SIZE 20" X 34" 9-5/8" WT. PER FT. 215.5# 40# 26# GRADE A53 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 109' 48" 28' 4963' 12-1/4" 26' 12366' 8-3/4" CEMENTING RECORD 260 sx Arctic Set (Approx.) 860 sx PF 'L" 298 sx Class 'G' 610 sx Class 'G' AMOUNT PUllED 7" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 4-1/2" Gun Diameter, 5 spf MD TVD 11184'-11194' 5166'- 5169' 11218' - 11238' 5177' - 5183' 11266' - 11276' 5192' - 5196' 11442' - 11462' 5249' - 5256' 11502' - 11522' 5269' - 5275' 11646'·11666' 5315'-5321' 11686' - 11706' 5328' - 5334' 11722' - 11742' 5339' - 5346' 11762' - 11782' 5352' - 5359' 27. Date First Production Not on Injection Date of Test Hours Tested SIZE 4-1/2", 12.6#, L-80 TUBING RECORD DEPTH SET (MD) 11400' PACKER SET (MD) 9421' & 11364' 25. MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 82 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Water Injection PRODUCTION FOR Oll-BBl TEST PERIOD GAs-McF WATER-BBl CHOKE SIZE GAS-Oil RATIO Flow Tubing Casing Pressure CALCULATED Oll-BBl GAs-McF WATER-BBl Oil GRAVITY-API (CORR) Press. 24-HoUR RATE 28. CORE DATA nCC[I\/CD Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core clii'S " ýd9~-3~' ~~:'.,,~ R8DMS BfL MAY 1 ~ Gr OR\G\N/ÄL MAY 1 ~ Z003 ï.nn~ I r, ro COI'IS Comm·,ss·\on ",Iaska u¡ :::{ uas . Anchorage No core samples were taken. Form 10-407 Rev. 07-01-80 Submit In Duplicate ) 29. Geologic Markers Marker Name Measured True Vertical Depth Depth Ugnu 6031' 3539' Ugnu M 9581' 4665' Schrader Bluff N 10369' 4916' Schrader Bluff 0 10982' 5102' OBa 11178' 5164' OBb 11314' 5208' aBc 11442' 5249' OBd 11640' 5313' OBe 11878' 5390' aBf 12030' 5439' Base Schrader Bluff a 12189' 5491' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys ) 30. Formation Tests Include interval tested. pressure data, all fluids recovered and gravity. GOR, and time of each phase. RECEI\/El) MAY J ~ 70n.1 Alaska Oil & Gas COilS. Commission Anchorage 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed rerrieHubble ~AJU1 ÞkJ~ T~le Technical Assistant Date OS -lfo-03 W-207i 203-049 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number P . / Drilling Engineer: Michael Triolo, 564-5774 ermlt No. Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection. water injection, steam injection. air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16. and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 28: If no cores taken, indicate 'none'. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. CO) i-'~ ; t· . t\ IlJ Form 10-407 Rev. 07-01-80 :" ¡ t\ 'L ( \~ j~.\ '. Legal Name: Common Name: Test Date 4/8/2003 LOT W-207i W-207i Test Type Test Depth (TMD) 4,995.0 (ft) Test Depth (T\lD) 3,197.0 (ft) EMW 13.11 (ppg) SurfåcePressure i,;,ØëikQffpressure (BHP) 650 (psi) 2,178 (psi) 9.20 (ppg) ~ --" Printed: 4/21/2003 2:40:15 PM ) ) BP Operations Summary Report Page 1 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-207i W-207i DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 3/31/2003 Rig Release: 4/19/2003 Rig Number: Spud Date: 4/2/2003 End: 4/19/2003 Date . From ~ To Hours Task· Code NPT Phase Description of Operations 4/1/2003 12:00 - 14:00 2.00 MOB P PRE Bridle up. Unpin blocks. Drop cattle chute. Unpin & lay derrick over. Camp, shop & pits moved to W-Pad. 14:00 - 18:30 4.50 MOB P PRE Pull sub off L-118 & move to W-207. 18:30 - 21 :00 2.50 MOB P PRE Lay mats & herculite. Spot sub over W-207. 21 :00 - 00:00 3.00 MOB P PRE Raise& pin derrick. Raise cattle chute. Bridle down & pin blocks. RU floor. Set support units & cuttings box. 4/2/2003 00:00 - 02:00 2.00 BOPSUR P PRE NU diverter, valves & riser. Rig acepted @ 0200 hrs on 4/2/2003. 02:00 - 04:00 2.00 RIGU P PRE Take on water & build spud mud. Load pipe shed w/ 5" DP. 04:00 - 07:00 3.00 RIGU P PRE Cut & slip 80' drlg line. Change out top drive quill f/4" HT-40 to 4.5" IF. Service top drive & blocks. Clean & prep rig for spud. 07:00 - 08:00 1.00 BOPSURP PRE Function test diverter. Witnesing waived by Jeff Jones-AOGCC Field Inspector. D3 Drill. 08:00 - 14:30 6.50 RIGU P PRE PU & stand back 47 stds 5" DP & 4 stds 5" HWDP. 14:30 - 15:00 0.50 DRILL P SURF Pre-Spud meeting with all personnel. 15:00 - 15:30 0.50 DRILL P SURF Fill hole. Check for leaks. Test mud lines-OK. 15:30 - 17:00 1.50 DRILL P SURF MU BHA. Orient MWD I Motor. 17:00 - 20:00 3.00 DRILL P SURF Tag up @ 108'. Drill f/108' to 352'. PU, SO, & Rot wt: 50k. 640 GPM w/ 750 psi. 80 RPM. 20:00 - 21 :00 1.00 DRILL P SURF Circ 15 min. Stand back HWDP. RIH w/ DC's & jar stand. 21 :00 - 00:00 3.00 DRILL P SURF Drld f/351' to 632'. Started kick off @ 400'. Sliding 75%-100%. 640 GPM w/ 959 psi. 4/3/2003 00:00 - 12:30 12.50 DRILL P SURF Drld f/632' to 1864'. PU: 94k; SO: 79k; RT: 80k; 650 GPM w/ 1500 psi; TO off: 3400; TO on: 6000. 80 RPM 12:30 - 13:30 1.00 DRILL P SURF Circ weighted sweep surf to surf. 13:30 - 15:30 2.00 DRILL P SURF POH. Intermittent tight spots. Wiped all out OK. Stand back BHA. 15:30 - 16:30 1.00 DRILL P SURF MU bit. RIH to 1768. Taking weight thru SV6. Worked down OK. 16:30 - 17:00 0.50 DRILL P SURF Fill pipe. Wash down to 1864'. 3' of fill on bottom. 17:00 - 00:00 7.00 DRILL P SURF Drlg fl 1864' to 3272'. PU: 11 Ok; SO: 80k; RT: 90k; 650 GPM wI 2000 psi; TO off: 4000; TO on: 9000. 80 RPM. Sliding 45 to 55% building angle as per plan. 4/4/2003 00:00 - 13:00 13.00 DRILL P SURF Drill 12 1/4" surface hole 3,272 ft to 4,933 ft. Hole section TD. P/U Wt 125k, SIO Wt 82k, Rot Wt 98k, 80 RPM, TO 11 k on btm, 8k off btm 650 GPM, 2000 psi off btm, 2385 psi on btm. Slide 215 ft. Avg TF 5 L Slide ROP 107 ft / hr. Rotate 1446 ft. Rotate ROP 259 ft I hr. AST= 2 hrs, ART= 5.58 hrs, ADT= 7.58 hrs. 13:00 - 17:00 4.00 DRILL P SURF Circ & cond mud. 650 GPM @ 2000 psi. Rotate & reciprocate. P/U Wt 125k, S/O Wt 82k, Rot Wt 98k, 80 RPM, TO 8k. 17:00 - 21 :00 4.00 DRILL P SURF POH w/12 1/4" bit to 2,330 ft. Work intermittent tight spots. 21 :00 - 22:00 1.00 DRILL P SURF Back ream 2,330 ft to 1,864 ft. 645 GPM @ 1700 psi 22:00 - 23:00 1.00 DRILL P SURF Blow down Top Drive. POH wI 12 1/4" bit to 400 ft. 23:00 - 00:00 1.00 DRILL P SURF RIH wI 121/4" bit to 1,700 ft. 4/5/2003 00:00 - 00:30 0.50 DRILL P SURF Con't RIH w/12 1/4" bit to 2,340. 00:30 - 01 :30 1.00 DRILL P SURF Ream 12 1/4" hole 2,340 to 2,707 ft. 250 GPM @ 600 psi, 20 RPM 01 :30 - 02:00 0.50 DRILL P SURF RIH w/12 1/4" bit 2,707 ft to 3,040 ft. Printed: 4/21/2003 2:40:21 PM ) ) BP Operéltions.$ummaryReþort Page 2of9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-207i W-207i DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 3/31/2003 Rig Release: 4/19/2003 Rig Number: Spud Date: 4/2/2003 End: 4/19/2003 . Date From -To Hours Task Code ·NPT phase Descri pHon of Oþerations 4/5/2003 02:00 - 03:30 1.50 DRILL P SURF Ream 3,040 ft to 3,080 ft. 250 GPM @ 650 psi, 20 RPM Unable to make progress. 03:30 - 04:30 1.00 DRILL P SURF Orient 12 1/4" bit, attempt to enter old hole sliding 'Highside'. 550 GPM @ 1550 psi. Confirm side track wI sUNey 2 deg drop from orginal well. 04:30 - 05:30 1.00 DRILL N DPRB SURF Circ & cond mud. Set up new well bore profile. 05:30 - 23:00 17.50 DRILL N DPRB SURF Drill 12 1/4" hole 3,140 ft to 4,975 ft hole section TD. P/U Wt 125k, S/O Wt 80k, Rot Wt 102k, 80 RPM's TO on btm 10k, TO off btm 6k. 647 GPM, 1950 psi off btm, 2100 psi on btm. WOB 35k. Slide 338 ft Avg TF HS Slide ROP= 91 ft I hr Rotate 1703 ft Rotate ROP 292 ft I hr AST= 3.7 hrs, ART= 5.83 hrs, ADT= 9.53 23:00 - 00:00 1.00 DRILL N DPRB SURF Circ & cond mud. Rotate & reciprocate pipe. P/U Wt 125k, S/O Wt 80k, Rot Wt 102k 647 GPM @ 1950 psi. 80 RPM's TO 6k. 4/6/2003 00:00 - 00:30 0.50 DRILL P SURF Circ & cond mud. Rotate & reciprocate pipe. 00:30 - 09:00 8.50 DRILL P SURF POH wI 12 1/4" bit back reaming as a precaution to 1,700 ft. P/U Wt 125k, S/O Wt 85k, Rot Wt 99k, 80 RPM's, TO 7-9k 650 GPM @ 1680 psi. 09:00 - 09:30 0.50 DRILL P SURF Circ btms up. Rot Wt 88k, 80 RPM's, TO 3k 650 GPM @ 1200 psi 09:30 - 11 :00 1.50 DRILL P SURF Con't POH w/12 1/4" bit to BHA @ 400 ft. 11 :00 - 13:00 2.00 DRILL P SURF Rack HWDP, jars & collars in derrick. LD MWD, MM & bit. 13:00 - 13:30 0.50 CASE P SURF Clean & clear rig floor. 13:30 -14:00 0.50 CASE P SURF PU mandrel hanger & landing jt. Make dummy run. LD same. 14:00 - 15:30 1.50 CASE P SURF RU 9 5/8" csg handling euip and fill up tool. 15:30 - 21 :30 6.00 CASE P SURF PU & RIH w/9 5/8" csg to 4,935 ft. Hole in good shape. Baker lock shoe track. Check floats O-K. Avg MU TO 7200 ftllbs 21 :30 - 22:00 0.50 CASE P SURF PU & MU landing jt wI FMC fluted mandrel hanger. Land casing wI shoe @ 4,963 ft. LD fill up tool. MU cmt head. 22:00 - 00:00 2.00 CEMT P SURF Circ & cond mud. Reciprocate pipe in 10ft strokes. RU HES cementers. P/U Wt 230k, S/O Wt 104k. 400 GPM @ 640 psi. 4/7/2003 00:00 - 01 :00 1.00 CEMT P SURF Circ & cond mud to 15 YP. 420 GPM @ 585 psi. Reciprocate pipe in 10ft strokes. P/U Wt 230k, S/O Wt 104k. 01 :00 - 02:00 1.00 CEMT P SURF Switch to Halliburton unit. Pump 5 bbls H20, test lines 3500 psi, pump 5 bbls H20, 75 bbls 10.2 ppg spacer. Pre heated H20 for cement at 90 deg F. Unable to mix cement. After contact wI Hot Water Plant it was discovered that the 'Sensor Probe' was faulty. Unable to reciprocate pipe. 02:00 - 06:00 4.00 CEMT N HMAN SURF Switch to rig pumps. Circ & cond mud to 18 YP. Mobilize 75 bbls spacer & 700 bbls 65 deg F H2O. 06:00 - 09:30 3.50 CEMT P SURF Switch to Halliburton unit. Pump 10 bbl H20, 75 bbls 10.2 ppg spacer, drop btm plug, pump 630 bbls 10.5 ppg 'Lead' slurry, 61 bbls 15.8 ppg 'Tail' slurry, drop top plug, chase w/1 0 bbls Printed: 4/21/2003 2:40:21 PM ) ) BP Operation!; SummCiry Report Page·3.of9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-207i W-207i DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 3/31/2003 Rig Release: 4/19/2003 Rig Number: Spud Date: 4/2/2003 End: 4/19/2003 Date From 7' To Hours Task Code NPT Phase Description of Operations 4/712003 06:00 - 09:30 3.50 CEMT P SURF H20. Switch to rig pumps pump 360 bbls mud. Bump plug wI 500 psi over FCP - 1980 psi. Cmt rate 7 BPM @ Avg 400 psi. Displ rate @ 7 BPM @ Avg 950 psi. 80 bbls cmt @ surface. Unable to reciprocate pipe. 09:30 - 10:30 1.00 CEMT P SURF Drain & flush all surface equip. Blow down same. RD cmt head & Landing jt. 10:30 - 12:00 1.50 CEMT P SURF RD csg handling equp. Clean excess cmt from drip pan. 12:00 - 15:00 3.00 DIVRTR P SURF Break out & LD riser and diverter. 15:00 - 18:00 3.00 BOPSURP SURF N/U Gen-5 Lower Split Unihead & 13 5/8" BOPE. FMC rep test metal to metal seal 1000 psi. O-K. 18:00 - 22:00 4.00 BOPSURP PROD1 Test BOPE as per BP & AOGCC regs to 250 / 4000 psi. Annular tested 250/3500 psi. Witness of test wavied by Chuck Scheve of AOGCC. 22:00 - 22:30 0.50 BOPSUB P PROD1 LD test jt. Blow down surface lines. Install wear ring. 22:30 - 00:00 1.50 DRILL P PROD1 PU 5" DP from pipe shed for next hole interval. 4/8/2003 00:00 - 02:30 2.50 DRILL P PROD1 PU 5" DP from pipe shed for next hole interval. 02:30 - 04:00 1.50 DRILL P PROD1 POH w/ 5" DP rack same in derrick. 04:00 - 08:00 4.00 DRILL P PROD1 PU BHA #3 with Hycalog DS-70 8 3/4 bit, 1.15 degree, 7 stage motor and MWD with MWD I GR I RES I Azimuth Den / Neu I PWD. Shallow test BHA 08:00 - 12:00 4.00 DRILL P PROD1 RIH picking up D.P. 1x1 from pipeshed to 4608. (Tested TAM port collar afte passing with BHA--Good test) 12:00 - 13:00 1.00 EVAL P PROD1 Pressure test 9 5/8 casing to 3,500 for 30 minutes on chart. Good test. 13:00 - 14:30 1.50 DRILL P PROD1 Slip and cut drilling line. Perform service work on Topdrive. 14:30 - 15:00 0.50 DRILL P PROD1 Establish bench line drilling parameters prior to drilling out float equipment. 15:00 - 16:30 1.50 DRILL P PROD1 Drill up shoe track plus 20' of new hole from 4876 to 4995. Up===144 Dwn==65 String=100 RPM==50 Trq===9,200 110,500 16:30 - 17:00 0.50 DRILL P PROD1 Displace wellbore to new 9.2 ppg. 65 vis LSND mud system. 17:00 - 17:30 0.50 DRILL P PROD1 Perform LOT to 13.11 ppg. with 650 suface pressure, 9.2 mud wt. 3197 TVD. 17:30 - 18:00 0.50 DRILL P PROD1 Establish baseline ECD's and drilling parameters. (10.62) SPR #1 @ 27 SPM=170 @ 40 SPM=230 SPR #2 @ 27 SPM=175 @ 40 SPM=230 18:00 - 00:00 6.00 DRILL P PROD1 Drill ahead in 8 3/4 hole section. Backreaming every connection at full drilling rate and reducing to 75% while reaming down. ART==2.29 AST== .25 WOB==10-12 GPM===600 @ 1900 PSI on bottom RPM===100 TRQ.===6,300 /8,500 4/9/2003 00:00 - 15:00 15.00 DRILL P PROD1 Drill 8 3/4 production hole from 5,927 to 7,700. Having to pick up off bottom and slow pumps due to shakers blinding off with heavy oils being drilled. (Order out EMI 712 detergent from MI Printed: 4/21/2003 2:40:21 PM ) ) BP Operations Summary Réport Page 4of9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-207i W-207i DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 3/31/2003 Rig Release: 4/19/2003 Rig Number: Spud Date: 4/2/2003 End: 4/19/2003 Date From :'- To Hours Task Code NPT Phase Description of Operations 4/912003 00:00 - 15:00 15.00 DRILL P PROD1 base) . 15:00 - 16:30 1.50 DRILL N FLUD PROD1 Slow pumps to 230 GPM and circ in 8 drums of "EMI-712" which arrived from MI plant. (This product is used like the BDF-263 which Baroid uses successfully to prevent screen blinding in this section of hole). Increase pumps to drilling rate as screens are cleared up. 16:30 - 00:00 7.50 DRILL P PROD1 Drilling ahead from 7,700 to 8,854. Pump Hi-vis sweeps every 200-300 ft. as hole dictates. Maintain effective ECD of .7 or under the calculated ECD by backreaming and circulating hole clean. ART===7.24 AST===1.74 WOB==5-20 GPM===600 @ 2500 on bottom TRQ===12,OOO 113,000 RPM===100 4/10/2003 00:00 - 00:00 24.00 DRILL P PROD1 Drilling 8 3/4 production hole from 8854 to 11,863. Pumping Hi-vis. fibre sweeps every 200 ft. with 4 ppb. Mix 2 medium. Backreaming each connection and circulating as required to maintain ECD value at or under +.7 over calculated. Adding lubricants to control torque. Current lube value at 3% with 50-50 blend of FLO-LUBE I LUBETEX. ART===10.5 AST===2.13 ADT===12.63 WOB==15-20 GPM===600 @ 2,900 on bottom RPM===100 TRQ===17,OOO-21 ,000 4/11/2003 00:00 - 03:00 3.00 DRILL P PROD1 Drilled 8314 production hole from 11,863 to 12,147. Blend in 250 bbls. of new 8.5 mud, treated with 3% lubes. Bring wt. back to 9.2 and lower MBT's. Up wt.==220K Dwn.==85K String==127K GPM==610 @ 2820 on bottom 2550 off TRQ==20-23,OOO off bottom 22,000 on RPM==100 WOB==15-20 Cal. ECD== 10.93 Actual ECD==11.63 Circulate sweeps every 200 ft., or as hole dictates. Adding Flolube and lubtex at 50/50 mix to control trq. Currently at 3%. 03:00 - 04:00 1.00 DRILL P PROD1 Circulate out LO-Hi fibre sweep to lower ECD's. 04:00 - 06:00 2.00 DRILL P PROD1 Drill 8 3/4 production hole to TD, from 12,147 to 12,380. AST==.41 ART==2.17 ADT==2.58 06:00 - 09:00 3.00 DRILL P PROD1 Circulate LO-Hi fibre sweep S-S while rotating and reciprocating. GPM==610 @ 2485 RPM==110 Trq.==21-23,000 09:00 - 13:30 4.50 DRILL P PROD1 POH slowly from 12,380 to 10,516. Intermittent swabbing and slight overpulls. Work pipe as needed to wipe hole. 13:30 - 00:00 10.50 DRILL P PROD1 POH backreaming from 10,516 to 5,238. Steady show of cuttings and wallcake coming over shakers during backreaming Printed: 4/21/2003 2:40:21 PM ') ) BP . Operations. SurnmaryReport Page 50f 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-207i W-207i DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 3/31/2003 Rig Release: 4/19/2003 Rig Number: Spud Date: 4/2/2003 End: 4/19/2003 Date From - To Hours Task Code NPT . Phase Descri ption of Operations 4/11/2003 13:30 - 00:00 10.50 DRILL P PROD1 operation. Maintain ECD's @ .7 or less under cal.. GPM==600 Trq===15,OOO to 19,000 RPM==110 4/12/2003 00:00 - 00:30 0.50 DRILL P PROD1 Backream to shoe from 5,238 to 4955. 00:30 - 01 :30 1.00 DRILL P PROD1 Circulate 2 ea. 25 bbl. Hi vis. Sweeps S-S. Lots of cuttings and wallcake with first sweep with minimal increase on second one. Rotate and reciprocate string at 110 RPM and 610 GPM. 01 :30 - 02:30 1.00 DRILL P PROD1 Slip and cut 60 ft. of drilling line. 02:30 - 03:00 0.50 DRILL P PROD1 Service topdrive. 03:00 - 06:30 3.50 DRILL P PROD1 RIH filling pipe at 7,311 and 9,672. Stage pumps up to drilling rate while watching ECD ceiling. Wash last stand to bottom with no adverse hole conditions or fill. 06:30 - 12:00 5.50 DRILL P PROD1 Circulate 40 bbl. Hi-Vis weighted sweep (2 pd. over mud weight) S-S. Good increase of cuttings brought out of hole both with bottoms up and sweep. Circulate and condition mud for running casing. Reduce YP to 15 and thin mud back. Calculated ECD's 10.11 Actual ECD's 10.26. Spot 500 BBLS. of new 9.2 mud, treated with 4 % lubes and 15 ppb. "G-Seal" ( Comparable to Baroids Steel Seal) Lube cocktail is 50-50 Lubtex and FloLube. GPM==610 @ 2390 PSI RPM==120 TRQ==23,000 UP==220,000 DWN==86,OOO STRING==144,OOO 12:00 - 12:30 0.50 DRILL P PROD1 POH standing back 10 stands in derrick. No adverse hole conditons. Hole taking proper fill. 12:30 - 21 :30 9.00 DRILL P PROD1 Pump dry job. Observe well. POH 1x1 recording up and down wts. every 1000 ft. in open hole and @ 4,800 and 2,500 inside 9 5/8 casing. Hole in good shape. 21 :30 - 00:00 2.50 DRILL P PROD1 Layout BHA. Remove nuke source. 4/13/2003 00:00 - 01 :00 1.00 DRILL P PROD1 Lay down BHA. Break and grade DS-70 bit. Grade: 4 3 CT A X I LT Clear floor of all excess vendors equipment. 01 :00 - 01 :30 0.50 BOPSUR P PROD1 Pull wear ring and install test plug. 01 :30 - 03:00 1.50 BOPSUR P COMP Change upper set of pipe rams to 7". Test door seals to 4,500 psi. 03:00 - 03:30 0.50 RUNCOIVP COMP Pick up landing joint with hanger assembly and make dummy run. Mark joint and record landing depth. 03:30 - 04:30 1.00 RIGU P COMP Rig up casing equipment and franks eirc. tool. Ready rig to run 7" long string. PJSM. 04:30 - 12:30 8.00 CASE P COMP Make up shoe track. Bakerlok first 2 connections. Check floats. RIH with 7" 26# L-80 BTC-M. Planned tally of 299 jts, 3 ea marker jts with RA bead in collars, float shoe, float collar, and FMC Mandrel hanger with a planned shoe depth of 12,366' MD. Torque connections to 8,000 ft Ibs using BEST-O-LlFE 2000 thread compound. Running procedure: Fill while lowering at 30 seconds per jt. Circ down every 10 jts for 5 minutes RIH to casing shoe at 4960'. 12:30 - 13:00 0.50 CASE P COMP Circulate at casing shoe 1.5 annulus volumes staging up to 7 Printed: 4/21/2003 2:4021 PM ') ') BP Op~rationsSu m maryReport Page 6 of9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-207i W-207i DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 3/31/2003 Rig Release: 4/19/2003 Rig Number: Spud Date: 4/2/2003 End: 4/19/2003 Date From "'-To Hours Task Code NPT Phase Description of Operations 4/13/2003 12:30 - 13:00 0.50 CASE P COMP BPM with no losses. 13:00 - 00:00 11.00 CASE P COMP RIH with 7" casing to 8890. Began pushing away mud immediately after entering open hole. Slow run speed to 4 minutes per jt. Circ for 5 minutes after each jts 5 run and 10 minutes after each 15 jts run. Bring bottoms up after every 50 jts while slowly running in hole. Record up and down weight every 15 jts run. Washing down at 3.5 BPM. Lost 19 bbls this 24 hour tour. 4/14/2003 00:00 - 10:00 10.00 CASE P COMP RIH with 7" casing from 8890 to 12,366. Tripping @ 4 minutes per jt. Circ for 5 minutes every 5 run and 10 minutes after every 15 jts run. Bring bottoms up after every 50 jts while slowly running in hole. Record up and down wt every 15 jts run. Washing down at 3.5 BPM. Total mud losses: This tour==============36 While running/cementing==55 10:00 - 12:30 2.50 CASE P COMP Circulate and condition mud for cement job. Stage up to 7 BPM @ 860 PSI. Reciprocate string with 200K up and 97K down. PJSM for cement job. 12:30 - 16:00 3.50 CEMT P COMP Pump 5 bbls. water. Pressure test lines to 4,500 PSI. Pump 35 bbls. Alpha spacer @ 10.2 ppg, drop bottom plug, then pump 125 bbls. 15.8 class "G" cement. Shut down and wash cement lines with 5 bbls. water. Drop and kick out top plug with 469.4 bbls. mud at 7 to 5 bbls. per minute. Reciprocated pipe until 30 bbls. cement had rounded corner, when difficulty coming back down required landing pipe on bottom. Reduced displacement rate from 7 to 5 BPM with 87 bbls. from bump. Bumped plug at 95% pump effeciency and held 3,500 PSI for 5 minutes. Bleed pressure and confirm floats are holding. CIP @ 14:30. RD cement equipment and landing joint. 16:00 - 17:30 1.50 RUNCOrvP COMP Flush stack and installltest Packoff to 5,000. 17:30 - 18:30 1.00 BOPSUR P COMP Change top rams from 7" to 3 1/2 X 6 variables. 18:30 - 20:30 2.00 RUNCOrvP COMP Change out Top drive quill and grabber jaw to accommodate new sting of 4" DP. 20:30 - 00:00 3.50 BOPSUR P COMP Test BOP equipment as per policy--250 low and 4,000 high. Witness of test waived by AOGCC representative "John Crisp". 4/15/2003 00:00 - 00:30 0.50 BOPSUR P COMP Pull test plug and install wear bushing. 00:30 - 01 :00 0.50 CLEAN P COMP Service Top drive. 01 :00 - 02:00 1.00 CLEAN P COMP M/U 6 1/8, used, tri-cone insert bit with no nozzles, scraper, MWD, Circ. sub., Hwdp, and jars. Shallow test MWD tool. 02:00 - 15:00 13.00 CLEAN P COMP RIH 1 x 1 with 4" DP to 11051'. Perform LOT on 7" X 9-5/8" annulus. Inject 100 bbls 9.2 ppg mud followed by 25 bbls seawater at 3 bpm and 725 psi. Freeze protect annulus by bullheading 69 bbls dead crude at 3.5 bpm and 1000 psi FCP. 15:00 - 16:00 1.00 PERF P COMP Log up from 11049' to 10943' @ 100 ftlhr 16:00 - 16:30 0.50 CLEAN P COMP Continue RIH 1 x 1 with 4" DP to 11680'. 16:30 - 18:00 1.50 PERF P COMP Log up from 11680' to 11595'. 180 gpm minimum circulation rate for MWD tool to function. Check circulating pressures: 180 gpm - 823 psi Printed: 412112003 2:40:21 PM ) ) BP Operations Summary Repo.rt Page'7öf9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-207i W-207i DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 3/31/2003 Rig Release: 4/19/2003 Rig Number: Spud Date: 4/2/2003 End: 4/19/2003 Date From'- To Hours Task Code NPT Phase Des.cri ptiOh. df Operations 4/15/2003 16:30 - 18:00 1.50 PERF P COMP 190 gpm - 882 psi 200 gpm - 950 psi 210 gpm -1030 psi 220 gpm - 1110 psi 230 gpm - 1190 psi 240 gpm - 1280 psi 250 gpm - 1350 psi MuD properties: 9.2 with 15 YP. 18:00 - 19:00 1.00 CLEAN P COMP Continue RIH, tag float collar at 12281' 19:00 - 22:00 3.00 CLEAN P COMP Circulate 40 bbls Safe Surf W, 40 bbls High Vis spacer, 170 bbls seawater. 5 bpm @ 1180 psi. Drop dart and open circ sub. Circulate 425 bbls 9.2 ppg brine surface to surface at 8 bpm and 1512 psi. 22:00 - 23:00 1.00 CLEAN P COMP Clean shakers and possum belly. Cut and slip 91' of drill line 23:00 - 23:30 0.50 CLEAN P COMP Spot 55 bbl perf pill on bottom, covers from PBTD to -200' above the OA sand 23:30 - 00:00 0.50 CLEAN P COMP Monitor well and POH for logs 4/16/2003 00:00 - 04:00 4.00 CLEAN P COMP Continue POH for logs 04:00 - 05:30 1.50 CLEAN P COMP Monitor well at BHA. Stand back 3 stands HWDP and LD BHA 05:30 - 06:00 0.50 CLEAN P COMP Clean and clear rig floor 06:00 - 07:00 1.00 CASE P COMP RU and test 7" casing to 4000 psi for 30 minutes - OK. 07:00 - 07:15 0.25 EVAL P COMP PJSM with SWS, and rig personel on rigging up and running USIT log 07:15 - 13:00 5.75 EVAL P COMP Run USIT log from 11500' to -7500'. Top of cement at 7850' TMD 13:00 -13:30 0.50 EVAL P COMP RD SWS 13:30 -14:00 0.50 PERF P COMP Service top drive and crown 14:00 - 14:30 0.50 PERF P COMP PJSM with HOWCO perf crew and rig personel on rigging up, making up and running perf guns. 14:30 - 16:30 2.00 PERF P COMP PU and MU perf guns 16:30 - 21 :30 5.00 PERF P COMP RIH with perf guns at 1 minute per stand 21 :30 - 22:00 0.50 PERF P COMP PU single joint of DP and RIH. Pick up to 14' mark on DP at 11793' MD. Pressure up DP and annulus to 3500 psi. Bleed off pressure. Fire Guns. 10 bblloss after perforating. 145 klbs up, 90 klbs down. the following intervals were perforated with 4-5/8" HOWCO Millennium charges at 5 spf. OBa sand perfs: 11184' to 11194' 11218' to 11238' 11266' to 11276' OBc sand perfs: 11442' to 11462' 11502' to 11522' OBd sand perfs: 11646' to 11666' 11686' to 11706' 11722' to 11742' 11762' to 11782' 22:00 - 23:30 1.50 PERF P COMP POH to 11184' to bring the perf guns above the top perforations. Monitor well- no flow. CBU, watching returns for Printed: 4/21/2003 2:40:21 PM ") ) BP OpetationsSu ml11a ryReport Page 8 of9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-207i W-207i DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 3/31/2003 Rig Release: 4/19/2003 Rig Number: Spud Date: 4/2/2003 End: 4/19/2003 Date From - To Hours Task Code NPT Phase Description of Operations 4/16/2003 22:00 - 23:30 1.50 PERF P COMP gas. 155 klbs up. 23:30 - 00:00 0.50 PERF P COMP Pull 1 stand to 11130'. The well started flowing back through the DP. MU top drive and CBU. Gas cut returns at bottoms up. 4/17/2003 00:00 - 00:30 0.50 PERF P COMP Continue CBU X 1.5 at 11130' 00:30 - 00:45 0.25 PERF P COMP Monitor well - flowing 00:45 - 01 :15 0.50 PERF P COMP Shut in well for 30 minutes and monitor pressure. No pressure increase 01 :15 - 01 :30 0.25 PERF P COMP Monitor well - flowing 01 :30 - 02:45 1.25 PERF P COMP CBU x 2, while increasing the brine weight from 9.2 ppg to 9.3 ppg 02:45 - 03:00 0.25 PERF P COMP Monitor well - no flow 03:00 - 07:00 4.00 PERF P COMP POH with perf guns, correct hole fill volumes on TOH. 150 klbs up, 85 klbs down. 07:00 - 07: 15 0.25 PERF P COMP PJSM with HOWCO and rig personel on laying down perf guns 07:15 - 09:00 1.75 PERF P COMP LD perf guns - all shots fired 09:00 - 09:30 0.50 CLEAN P COMP Clean and clear rig floor 09:30 - 10:30 1.00 CLEAN P COMP Monitor well. MU BHA #6, scraper / boot basket. 10:30 - 15:00 4.50 CLEAN P COMP RIH with scraper and boot basket for cleanout run. Fill every 3000'. 15:00 - 15:30 0.50 CLEAN P COMP Tag up on float collar at 12281'. Backream 90' at 40 rpms then POH 9 stands to 11360'. 165 klbs up, 90 klbs down. 15:30 - 16:30 1.00 CLEAN P COMP CBU at max rate of 10 bpm, 2225 psi. Reciprocate at 100 rpm. 160 klbs up, 85 klbs down, 108 klbs rotate. 16:30 - 17:30 1.00 CLEAN P COMP POH to run tbg. stand back 26 stands to be kept in derrick on rig move. 17:30 - 22:00 4.50 CLEAN P COMP Continue POH laying down DP to 2100' 22:00 - 23:00 1.00 CLEAN P COMP Cut and slip 81' of drill line, adjust brakes 23:00 - 00:00 1.00 CLEAN P COMP Continue POH laying down DP. 19 bblloss on TOH 4/18/2003 00:00 - 00:30 0.50 CLEAN P COMP Continue POH laying down DP 00:30 - 01 :30 1.00 CLEAN P COMP Stand back 3 stands HWDP. LD BHA, 1/4 cup of metal shavings recovered from boot basket 01 :30 - 02:30 1.00 BOPSUR P COMP Pull wear bushing. Flush stack. PU landing joint, MU tbg hanger, make dummy run. 02:30 - 03:30 1.00 RUNCOrvP COMP Rig up tbg equipment, compensator. CO bails. 03:30 - 03:45 0.25 RUNCOrvP COMP PJSM with Baker, Nabors Casing and rig personnel on running 4-1/2" tbg. 03:45 - 00:00 20.25 RUNCOrvP COMP Run 4-1/2" 12.6# TC-II dual packer completion string. Torque turn each joint 2700 ftlbs, with Jet Lube seal Guard. Rough threads were causing torque spikes before the joints were completely made up. Used an emery cloth to deburr and smooth the last 3 or 4 threads on each joint prior to make up. Slowed the run time down from 20-25 jtslhr to 10-15 jts/hr. 4/19/2003 00:00 - 01 :00 1.00 RUNCOrvP COMP Continue to run 4-1/2" 12.6# TC-II tubing 01 :00 - 01 :30 0.50 RUNCOrvP COMP MU landing joint. Land tbg. RILDS 01 :30 - 04:00 2.50 RUNCOrvP COMP Reverse Circulate 173 bbls clean 9.3 ppg NACL brine, 93 bbls corrosion inhibited brine and 82 bbls clean 9.3 ppg NACL brine to place corrosion inhibited seawater between the GLM and the upper packer 04:00 - 04:30 0.50 RUNCOrvP COMP Drop rod and ball with roller assembly. RD landing jnt. RU test pump Printed: 4/21/2003 2:40:21 PM ') ) BP Op~rations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-207i W-207i DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Date From - To Hours Task Code NPT Phase 4/19/2003 04:30 - 05:00 0.50 RUNCOIVP COMP 05:00 - 05:30 0.50 RUNCOIVP COMP 05:30 - 06:30 1.00 RUNCOIVP COMP 06:30 - 07:30 1.00 BOPSUR P COMP 07:30 - 09:30 2.00 BOPSUR P COMP 09:30 - 12:00 2.50 WHSUR P COMP 12:00 - 12:30 0.50 WHSUR P COMP 12:30 - 13:00 0.50 WHSUR P COMP 13:00 - 14:00 1.00 WHSUR P COMP 14:00 - 15:00 1.00 WHSUR P COMP 15:00 - 16:00 1.00 WHSUR P COMP Page 90f 9 Start: 3/31/2003 Rig Release: 4/19/2003 Rig Number: Spud Date: 4/2/2003 End: 4/19/2003 Desctiptionof Operations Pressure up tbg to 2800 psi with rig pump to set Baker S-3 packer. Switch to test pump and pressure up to 4200 psi to set Baker Premier packer. Reduce pressure to 4000 psi and hold for 30 minute tbg. test. Reduce tbg pressure to 2500 psi. Pressure up 4-1/2" X 7" annulus to 4000 psi for 30 minutes. Bleed down annulus and tbg pressure to O. Repressure annulus to 2700 psi to shear DCK valve. Blow down lines. Install TWC, test tp 1000 psi - OK ND BOPE, riser. LD mouse hole NU adapter and tree. RU up to test Test adapter flange and tree to 5000 psi - OK RU DSM and pull TWC RU and reverse circulate 82 bbls diesel down 7" X 4-1/2" annulus Allow diesel to U-tube to tbg. Install BPV, test from below to 1000 psi - OK. Install VR plugs in 7" X 4-1/2" annulus valves. Secure tree and cellar. Rig released at 16:00 hrs. Printed: 4/21/2003 2:40:21 PM bp W-207PB1 Schlumberger Survey Report - Geodetic Report Date: 4-Apr-03 Survey I DLS Computation Method: Minimum Curvature I Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 105.690° Field: Prudhoe Bay Unit - WOA (Drill Pads) Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: W-PAD / W-207 TVD Reference Datum: KB Well: W-207 TVD Reference Elevation: 80.900 ft relative to MSL Borehole: W-207PB1 Sea Bed I Ground Level Elevation: 47.830 ft relative to MSL UWIIAPI#: 500292314570 Magnetic Declination: +25.662° Survey Name I Date: W-207PB1 I April 4, 2003 Total Field Strength: 57520.884 nT Tort I AHD I DDII ERD ratio: 92.32]0 13057.20 ft I 5.638 / 0.954 Magnetic Dip: 80.777° ~ Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: April 25, 2003 Location Lat/Long: N 70.29764651, W 149.09260374 Magnetic Declination Model: BGGM 2002 Location Grid N/E Y/X: N 5959261.380 ftUS, E 612049.200 ftUS North Reference: True North Grid Convergence Angle: +0.85428243° Total Corr Mag North -> True North: +25.662° Grid Scale Factor: 0.99991426 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S EI-W DLS Northing Easting Latitude Longitude (ft) n n (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5959261.38 612049.20 N 70.29764651 W 149.09260374 190.59 1.07 143.77 190.58 1.40 -1 .44 1.05 0.56 5959259.96 612050.27 N 70.29764259 W 149.09259522 282.46 1.16 140.24 282.43 2.84 -2.84 2.15 0.12 5959258.57 612051.40 N 70.29763875 W 149.09258630 381.40 1.45 137.68 381.35 4.73 -4.54 3.64 0.30 5959256.90 612052.90 N 70.29763412 W 149.09257429 475.60 3.28 126.80 475.46 8.25 -7.03 6.60 1.99 5959254.45 612055.90 N 70.29762730 W 149.09255032 568.98 5.36 117.94 568.57 15.01 -10.68 12.59 2.33 5959250.89 612061.95 N 70.29761734 W 149.09250179 664.45 7.54 115.49 663.43 25.54 -15.46 22.18 2.30 5959246.25 612071.61 N 70.29760427 W 149.09242410 760.05 9.14 109.68 758. 02 39.30 -20.72 35.00 1.89 5959241.19 612084.50 N 70.29758991 W 149.0923203e 854.45 10.89 106.48 850.98 55.69 -25.77 50.61 1.94 5959236.36 612100.18 N 70.29757610 W 149.09219395 ~ 949.38 12.90 102.04 943.87 75.24 -30.53 69.57 2.32 5959231.89 612119.21 N 70.29756311 W 149.09204039 1045.03 15.41 99.52 1036.61 98.53 -34.86 92.55 2.70 5959227.91 612142.25 N 70.29755128 W 149.09185433 1138.63 17.59 98.32 1126.35 124.92 -38.96 118.81 2.36 5959224.20 612168.57 N 70.29754007 W 149.09164168 1233.25 19.19 95.28 1216.13 154.40 -42.46 148.45 1.97 5959221.14 612198.25 N 70.29753050 W 149.09140173 1329.24 20.08 98.11 1306.54 186.25 -46.24 180.47 1.36 5959217.84 612230.33 N 70.29752018 W 149.09114244 1422.43 23.81 100.17 1392.97 220.85 -51.82 214.84 4.09 5959212.77 612264.77 N 70.29750494 W 149.09086418 1517.70 25.40 99.10 1479.58 260.29 -58.45 253.94 1.73 5959206.73 612303.97 N 70.29748683 W 149.09054754 1611 .50 28.48 99.37 1563.20 302.51 -65.27 295.88 3.29 5959200.53 612346.00 N 70.29746818 W 149.09020795 1707.10 30.13 96.82 1646.56 348.88 -71.83 342.20 2.16 5959194.66 612392.41 N 70.29745025 W 149.08983291 W-207PB1 ASP Final Survey.xls Schlumberger Private Page 1 of 2 5/16/2003-8:34 AM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S EI-W DLS Northing Easting Latitude Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 1801.43 31.56 97.65 1727.55 396.72 -77.93 390.18 1.58 5959189.28 612440.46 N 70.29743358 W 149.08944445 1894.15 32.46 100.69 1806.17 445.53 -85.78 438.68 1.99 5959182.16 612489.07 N 70.29741214 W 149.08905172 1989.07 35.79 103.17 1884.74 498.65 -96.83 490.75 3.80 5959171.89 612541.30 N 70.29738194 W 149.08863009 2082.22 37.21 102.20 1959.62 553.98 -108.99 544.81 1.65 5959160.54 612595.53 N 70.29734871 W 149.08819242 2176.18 40.26 101.03 2032.91 612.62 -120.80 602.39 3.34 5959149.58 612653.27 N 70.29731642 W 149.08772618 2271.30 39.07 100.93 2106.13 673.13 -132.37 661.99 1.25 5959138.91 612713.04 N 70.29728481 W 149.08724359 2365.36 41.44 102.85 2177.91 733.76 -144.91 721.46 2.84 5959127.25 612772.67 N 70.29725052 W 149.08676214 2458.98 42.20 102.66 2247.68 796.11 -158.70 782.34 0.82 5959114.38 612833.75 N 70.29721286 W 149.08626918 2553.93 47.49 103.01 2314.98 862.96 -173.57 847.60 5.58 5959100.48 612899.22 N 70.29717219 W 149.08574079 2645.96 50.97 102.76 2375.07 932.56 -189.11 915.53 3.79 5959085.96 612967.37 N 70.29712973 W 149.08519076'~ 2738.81 53.44 102.75 2431.96 1005.83 -205.31 987.09 2.66 5959070.83 613039.15 N 70.29708545 W 149.08461140 2833.34 54.88 105.27 2487.32 1082.42 -223.87 1061.42 2.64 5959053.38 613113.75 N 70.29703471 W 149.08400953 2927.41 60.20 105.41 2537.79 1161.76 -244.86 1137.94 5.66 5959033.53 613190.56 N 70.29697733 W 149.08339001 3021.21 63.22 106.16 2582.24 1244.34 -267.34 1217.41 3.30 5959012.25 613270.35 N 70.29691590 W 149.08274659 3117.55 66.94 106.91 2622.82 1331.69 -292.21 1301.15 3.93 5958988.63 613354.45 N 70.29684792 W 149.08206860 3211 . 14 68.05 107.72 2658.65 1418.12 -317.94 1383.69 1.43 5958964.13 613437.36 N 70.29677757 W 149.08140032 3304.06 70.23 107.01 2691.73 1504.90 -343.85 1466.56 2.45 5958939.46 613520.59 N 70.29670675 W 149.08072940 3398.29 71.56 107.46 2722.57 1593.91 -370.23 1551.60 1.48 5958914.35 613606.01 N 70.29663463 W 149.08004090 3492.79 70.82 107.56 2753.04 1683.31 -397.15 1636.91 0.79 5958888.72 613691.70 N 70.29656105 W 149.07935024 3586.51 70.19 107.59 2784.32 1771.61 -423.82 1721.13 0.67 5958863.30 613776.30 N 70.29648812 W 149.07866836 3678.77 71.28 106.61 2814.76 1858.68 -449.43 1804.37 1.55 5958838.94 613859.91 N 70.29641811 W 149.07799443 3772.94 70.58 107.29 2845.53 1947.66 -475.38 1889.51 1.01 5958814.27 613945.42 N 70.29634717 W 149.07730518 3866.73 71.88 108.03 2875.71 2036.40 -502.32 1974.12 1.57 5958788.59 614030.41 N 70.29627351 W 149.07662016 3960.42 71.45 107.59 2905.18 2125.28 -529.52 2058.79 0.64 5958762.66 614115.47 N 70.29619914 W 149.07593467 4054.04 70.80 107.86 2935.47 2213.81 -556.49 2143.17 0.75 5958736.95 614200.24 N 70.29612540 W 149.0752515t 4149.67 71.85 107.59 2966.09 2304.34 -584.07 2229.46 1.13 5958710.67 614286.93 N 70.29604998 W 149.07455294 ~ 4242.86 72.24 108.69 2994.81 2392.91 -611.67 2313.71 1.20 5958684.33 614371.57 N 70.29597451 W 149.07387093 4337.92 71.53 108.34 3024.37 2483.15 -640.36 2399.38 0.82 5958656.92 614457.65 N 70.29589605 W 149.07317738 4432.03 72.12 108.41 3053.73 2572.46 -668.55 2484.23 0.63 5958630.00 614542.91 N 70.29581897 W 149.07249043 4525.71 72.24 109.28 3082.39 2661.51 -697.35 2568.64 0.89 5958602.46 614627.72 N 70.29574020 W 149.07180714 4621.50 72.39 109.32 3111 .49 2752.60 -727.52 2654.77 0.16 5958573.58 614714.29 N 70.29565771 W 149.07110986 4714.09 73.14 109.16 3138.93 2840.86 -756.66 2738.26 0.83 5958545.70 614798.20 N 70.29557802 W 149.07043396 4811.82 72.81 108.77 3167.54 2934.15 -787.03 2826.64 0.51 5958516.65 614887.01 N 70.29549496 W 149.06971855 4869.18 72.29 109.10 3184.74 2988.78 -804.78 2878.40 1.06 5958499.67 614939.02 N 70.29544640 W 149.06929955 4933.00 72.29 109.10 3204.16 3049.47 -824.68 2935.85 0.00 5958480.64 614996.76 N 70.29539199 W 149.06883450 Schlumberger Private W-207PB1 ASP Final Survey.xls Page 2 of 2 5/16/2003-8:34 AM bp W-207 Schlumbepgep Survey Report - Geodetic Report Date: 11-Apr-03 Survey I DLS Computation Method: Minimum Curvature I Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 106.080° Field: Prudhoe Bay Unit - WOA (Drill Pads) Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: W-PAD / W-207 TVD Reference Datum: KB Well: W-207 TVD Reference Elevation: 80.900 ft relative to MSL Borehole: W-207 Sea Bed I Ground Level Elevation: 47.830 ft relative to MSL UWI/API#: 500292314500 Magnetic Declination: +25.662° Survey Name 1 Date: W-207 I April 11 , 2003 Total Field Strength: 57520.884 nT Tort I AHD 1 DDII ERD ratio: 165.301 ° /10122.65 ft /6.572 I 1.822 Magnetic Dip: 80.777° .~ Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: April 25,2003 Location Lat/Long: N 70.29764651, W 149.09260374 Magnetic Declination Model: BGGM 2002 Location Grid N/E Y/X: N 5959261.380 ftUS, E 612049.200 ftUS North Reference: True North Grid Convergence Angle: +0.85428243° Total Corr Mag North -> True North: +25.662° Grid Scale Factor: 0.99991426 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S EJ-W DLS Northing Easting Latitude Longitude (ft) (0) n (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5959261.38 612049.20 N 70.29764651 W 149.09260374 190.59 1.07 143.77 190.58 1.41 -1 .44 1.05 0.56 5959259.96 612050.27 N 70.29764259 W 149.09259522 282.46 1.16 140.24 282.43 2.86 -2.84 2.15 0.12 5959258.57 612051.40 N 70.29763875 W 149.09258630 381 .40 1.45 137.68 381.35 4.75 -4.54 3.64 0.30 5959256.90 612052.90 N 70.29763412 W 149.09257429 475.60 3.28 126.80 475.46 8.29 -7.03 6.60 1.99 5959254.45 612055.90 N 70.29762730 W 149.09255032 568.98 5.36 117.94 568.57 15.06 -10.68 12.59 2.33 5959250.89 612061.95 N 70.29761734 W 149.09250179 664.45 7.54 115.49 663.43 25.60 -15.46 22.18 2.30 5959246.25 612071.61 N 70.29760427 W 149.09242410 760.05 9.14 109.68 758.02 39.37 -20.72 35.00 1.89 5959241.19 612084.50 N 70.29758991 W 149.0923203E 854.45 10.89 106.48 850.98 55.77 -25.77 50.61 1.94 5959236.36 612100.18 N 70.29757610 W 149.09219395--- 949.38 12.90 102.04 943.87 75.31 -30.53 69.57 2.32 5959231.89 612119.21 N 70.29756311 W 149.09204039 1045.03 15.41 99.52 1036.61 98.59 -34.86 92.55 2.70 5959227.91 612142.25 N 70.29755128 W 149.09185433 1138.63 17.59 98.32 1126.35 124.96 -38.96 118.81 2.36 5959224.20 612168.57 N 70.29754007 W 149.09164168 1233.25 19.19 95.28 1216.13 154.40 -42.46 148.45 1.97 5959221.14 612198.25 N 70.29753050 W 149.09140173 1329.24 20.08 98.11 1306.54 186.22 -46.24 180.47 1.36 5959217.84 612230.33 N 70.29752018 W 149.09114244 1422.43 23.81 100.17 1392.97 220.79 -51.82 214.84 4.09 5959212.77 612264.77 N 70.29750494 W 149.09086418 1517.70 25.40 99.10 1479.58 260.20 -58.45 253.94 1.73 5959206.73 612303.97 N 70.29748683 W 149.09054754 1611 .50 28.48 99.37 1563.20 302.39 -65.27 295.88 3.29 5959200.53 612346.00 N 70.29746818 W 149.09020795 1707.10 30.13 96.82 1646.56 348.71 -71.83 342.20 2.16 5959194.66 612392.41 N 70.29745025 W 149.08983291 W-207 ASP Final Survey.xls Schlumberger Private Page 1 of 5 5/16/2003-8:34 AM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S EI-W DLS Northing Easting Latitude Longitude (ft) n n (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 1801.43 31.56 97.65 1727.55 396.50 -77.93 390.18 1.58 5959189.28 612440.46 N 70.29743358 W 149.08944445 1894.15 32.45 100.69 1806.18 445.27 -85.78 438.68 1.98 5959182.16 612489.07 N 70.29741214 W 149.08905178 1989.07 35.78 103.18 1884.76 498.35 -96.83 490.73 3.80 5959171.88 612541.28 N 70.29738194 W 149.08863027 2082.22 37.20 102.19 1959.65 553.65 -108.99 544.78 1.65 5959160.54 612595.49 N 70.29734872 W 149.08819270 2176.18 40.25 101.02 2032.94 612.24 -120.79 602.35 3.34 5959149.59 612653.23 N 70.29731646 W 149.08772654 2271.30 39.07 100.91 2106.17 672.70 -132.34 661.95 1.24 5959138.94 612712.99 N 70.29728490 W 149.08724397 2365.36 41 .43 102.81 2177.95 733.31 -144.85 721.41 2.83 5959127.31 612772.63 N 70.29725070 W 149.08676252 2458.98 42.19 102.65 2247.73 795.61 -158.60 782.29 0.82 5959114.47 612833.70 N 70.29721311 W 149.08626960 2553.93 47.49 102.98 2315.04 862.43 -173.46 847.55 5.59 5959100.59 612899.16 N 70.29717252 W 149.08574122 2645.96 50.96 102.77 2375.13 932.00 -188.98 915.48 3.77 5959086.09 612967.31 N 70.29713008 W 149.08519121 '~ 2738.81 53.44 102.76 2432.04 1005.24 -205.19 987.02 2.67 5959070.95 613039.09 N 70.29708578 W 149.08461191 2833.34 54.88 105.26 2487.39 1081.81 -223.75 1061.36 2.63 5959053.50 613113.69 N 70.29703504 W 149.08401004 2927.41 60.20 105.40 2537.86 1161.15 -244.73 1137.88 5.66 5959033.66 613190.50 N 70.29697769 W 149.08339049 3023.27 62.59 105.79 2583.75 1245.30 -267.36 1218.94 2.52 5959012.25 613271.88 N 70.29691584 W 149.08273424 3113.70 64.93 106.91 2623.73 1326.40 -290.20 1296.76 2.82 5958990.57 613350.03 N 70.29685341 W 149.08210416 3209.92 69.55 106.56 2660.95 1415.10 -315.73 1381.70 4.81 5958966.31 613435.34 N 70.29678361 W 149.08141640 3304.24 71.18 105.63 2692.64 1503.93 -340.36 1467.06 1.96 5958942.96 613521.04 N 70.29671629 W 149.08072537 3398.61 72.41 105.45 2722.12 1593.57 -364.37 1553.42 1.32 5958920.24 613607.75 N 70.29665063 W 149.08002612 3492.76 73.51 105.62 2749.71 1683.58 -388.48 1640.15 1.18 5958897.43 613694.81 N 70.29658472 W 149.07932396 3586.55 72.12 104.93 2777.42 1773.17 -412.09 1726.58 1.64 5958875.11 613781.58 N 70.29652017 W 149.07862417 3680.06 72.92 105.63 2805.51 1862.35 -435.60 1812.62 1.11 5958852.89 613867.95 N 70.29645590 W 149.07792760 3774.59 72.71 105.45 2833.44 1952.66 -459.79 1899.63 0.29 5958830.00 613955.31 N 70.29638974 W 149.07722318 3868.24 72.31 104.87 2861.59 2041.97 -483.15 1985.84 0.73 5958807.93 614041 .85 N 70.29632587 W 149.07652521 3961.35 71.70 104.81 2890.35 2130.50 -505.83 2071.44 0.66 5958786.53 614127.77 N 70.29626384 W 149.07583218 4053.46 72.08 104.79 2918.98 2218.03 -528.19 2156.08 0.41 5958765.43 614212.73 N 70.29620268 W 149.0751469~ 4150.46 71.06 106.84 2949.65 2310.04 -553.27 2244.62 2.26 5958741.69 614301.62 N 70.29613411 W 149.07443015~ 4244.02 73.26 107.17 2978.31 2399.09 -579.31 2329.78 2.38 5958716.91 614387.15 N 70.29606289 W 149.07374070 4339.06 72.33 107.15 3006.42 2489.86 -606.10 2416.53 0.98 5958691.43 614474.28 N 70.29598964 W 149.07303845 4429.85 71.63 106.84 3034.51 2576.18 -631.33 2499.09 0.84 5958667.43 614557.21 N 70.29592062 W 149.07237003 4527.05 73.04 106.74 3064.00 2668.79 -658.09 2587.76 1.45 5958642.00 614646.25 N 70.29584745 W 149.07165222 4622.67 72.20 106.67 3092.57 2760.04 -684.32 2675.16 0.88 5958617.08 614734.03 N 70.29577571 W 149.07094465 4718.31 71.39 107.19 3122.45 2850.88 -710.77 2762.08 0.99 5958591.93 614821.32 N 70.29570335 W 149.07024104 4811.52 72.68 106.69 3151.20 2939.53 -736.61 2846.89 1.48 5958567.36 614906.51 N 70.29563269 W 149.06955441 4905.96 72.34 106.44 3179.58 3029.60 -762.29 2933.23 0.44 5958542.97 614993.21 N 70.29556244 W 149.06885550 4999.86 70.80 106.53 3209.26 3118.68 -787.56 3018.65 1.64 5958518.98 615078.99 N 70.29549329 W 149.06816400 Schlumberger Private W-207 ASP Final Survey. xis Page 2 of 5 5/16/2003-8:34 AM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S EJ-W DLS Northing Easting Latitude Longitude (ft) r) r) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 5093.92 70.35 105.91 3240.55 3207.39 -812.34 3103.82 0.78 5958495.47 615164.51 N 70.29542551 W 149.06747449 5189.56 71.56 106.95 3271.75 3297.79 -837.91 3190.53 1.63 5958471.20 615251.59 N 70.29535555 W 149.06677256 5285.22 71.68 106.70 3301.92 3388.56 -864.19 3277.42 0.28 5958446.22 615338.86 N 70.29528366 W 149.06606914 5379.25 71.59 106.34 3331.54 3477.80 -889.57 3362.98 0.38 5958422.13 615424.77 N 70.29521423 W 149.06537655 5473.74 70.71 106.11 3362.07 3567.22 -914.55 3448.84 0.96 5958398.43 615510.99 N 70.29514587 W 149.06468151 5568.79 72.19 106.59 3392.31 3657.33 -939.92 3535.31 1.63 5958374.35 615597.81 N 70.29507645 W 149.06398158 5660.85 72.61 105.39 3420.15 3745.08 -964.09 3619.66 1.32 5958351.44 615682.51 N 70.29501031 W 149.06329874 5755.69 71.95 108.57 3449.02 3835.39 -990.46 3706.05 3.27 5958326.36 615769.28 N 70.29493814 W 149.06259943 5849.56 71.29 108.02 3478.62 3924.41 -1018.43 3790.63 0.90 5958299.66 615854.26 N 70.29486163 W 149.06191480 5943.20 70.47 107.61 3509.29 4012.84 -1045.50 3874.86 0.97 5958273.86 615938.87 N 70.29478757 W 149.06123298'---' 6037.47 71.20 107.44 3540.24 4101.85 -1072.31 3959.77 0.79 5958248.32 616024.17 N 70.29471419 W 149.06054565 6132.49 71.44 106.16 3570.67 4191.86 -1098.33 4045.94 1.30 5958223.59 616110.71 N 70.29464300 W 149.05984813 6227.47 70.59 106.85 3601.57 4281.67 -1123.84 4132.05 1.13 5958199.36 616197.18 N 70.29457317 W 149.05915109 6323.50 71.43 109.05 3632.82 4372.42 -1151.83 4218.43 2.34 5958172.67 616283.96 N 70.29449658 W 149.05845194 6417.48 71 .46 108.34 3662.73 4461 .42 -1180.38 4302.82 0.72 5958145.38 616368.76 N 70.29441843 W 149.05776883 6511.48 70.68 109.34 3693.22 4550.23 -1209.10 4386.97 1.30 5958117.93 616453.32 N 70.29433986 W 149.05708770 6606.35 72.13 110.34 3723.48 4639.95 -1239.61 4471.55 1.83 5958088.67 616538.34 N 70.29425635 W 149.05640314 6700.79 71.86 109.47 3752.67 4729.56 -1270.19 4556.00 0.92 5958059.36 616623.23 N 70.29417267 W 149.05571961 6794.92 70.56 110.02 3782.99 4818.49 -1300.30 4639.87 1.49 5958030.51 616707.53 N 70.29409029 W 149.05504076 6887.88 72.01 110.26 3812.81 4906.31 -1330.61 4722.53 1.58 5958001.44 616790.62 N 70.29400733 W 149.05437173 6981.69 71.64 109.60 3842.07 4995.24 -1360.99 4806.32 0.78 5957972.31 616874.85 N 70.29392419 W 149.05369355 7075.03 70.66 109.37 3872.23 5083.42 -1390.46 4889.59 1.08 5957944.09 616958.55 N 70.29384355 W 149.05301955 7169.00 71.38 110.37 3902.79 5172.08 -1420.66 4973.16 1.26 5957915.14 617042.55 N 70.29376088 W 149.05234317 7263.79 71.34 110.49 3933.09 5261.64 -1452.01 5057.33 0.13 5957885.05 617127.17 N 70.29367508 W 149.05166195 7358.11 72.40 109.84 3962.44 5351.05 -1482.91 5141.47 1.30 5957855.41 617211.75 N 70.29359051 W 149.05098096-.-' 7451. 1 0 72.97 107.38 3990.12 5439.73 -1511.24 5225.60 2.60 5957828.35 617296.29 N 70.29351297 W 149.05030006 7545.85 73.08 107.53 4017.78 5530.33 -1538.42 5312.05 0.19 5957802.46 617383.12 N 70.29343854 W 149.04960037 7640.53 71.62 106.02 4046.49 5620.54 -1564.46 5398.42 2.17 5957777.71 617469.87 N 70.29336723 W 149.04890127 7734.74 71.11 105.85 4076.60 5709.81 -1588.97 5484.26 0.57 5957754.48 617556.06 N 70.29330010 W 149.04820650 7829.68 71.32 105.96 4107.17 5799.69 -1613.60 5570.70 0.25 5957731.15 617642.85 N 70.29323264 W 149.04750687 7923.65 71.25 106.10 4137.32 5888.69 -1638.18 5656.24 0.16 5957707.85 617728.74 N 70.29316532 W 149.04681454 8019.21 71.07 105.70 4168. 18 5979.13 -1662.96 5743.22 0.44 5957684.37 617816.07 N 70.29309745 W 149.04611056 8114.44 70.77 105.17 4199.31 6069.12 -1686.91 5829.98 0.61 5957661.72 617903.17 N 70.29303183 W 149.04540843 8206.06 70.05 106. 16 4230.03 6155.44 -1710.21 5913.09 1.29 5957639.66 617986.61 N 70.29296799 W 149.04473579 8300.47 71.11 106. 17 4261.42 6244.47 -1735.00 5998.60 1.12 5957616.15 618072.48 N 70.29290008 W 149.04404366 Schlumberger Private W-207 ASP Final Survey. xis Page 3 of 5 5/16/2003-8:34 AM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S EI-W DLS Northing Easting Latitude Longitude (ft) (0) n (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 8396.62 70.35 106.53 4293.15 6335.23 -1760.55 6085.70 0.87 5957591.90 618159.93 N 70.29283009 W 149.04333880 8490.42 72.45 106.60 4323.07 6424.13 -1785.90 6170.90 2.24 5957567.83 618245.50 N 70.29276066 W 149.04264921 8585.54 71.86 107.77 4352.22 6514.65 -1812.65 6257.40 1.32 5957542.38 618332.38 N 70.29268739 W 149.04194916 8681.00 71.22 108.34 4382.44 6605.14 -1840.71 6343.49 0.88 5957515.61 618418.87 N 70.29261053 W 149.04125245 8775.77 71.32 108. 14 4412.87 6694.83 -1868.80 6428.73 0.23 5957488.79 618504.51 N 70.29253359 W 149.04056261 8868.41 71.38 107.76 4442.50 6782.56 -1895.85 6512.23 0.39 5957462.99 618588.40 N 70.29245949 W 149.03988683 8961.81 71.59 106.92 4472.16 6871.10 -1922.25 6596.77 0.88 5957437.86 618673.32 N 70.29238718 W 149.03920267 9057.38 72.19 105.97 4501.87 6961.94 -1947.96 6683.89 1.13 5957413.45 618760.80 N 70.29231672 W 149.03849762 9151.01 71.92 105.55 4530.71 7051.01 -1972.16 6769.62 0.52 5957390.54 618846.87 N 70.29225042 W 149.03780385 9246.08 72.37 106.12 4559.86 7141.50 -1996.85 6856.67 0.74 5957367.15 618934.28 N 70.29218274 W 149.03709931c"-",, 9339.24 72.36 1 06.20 4588.09 7230.28 -2021.56 6941.95 0.08 5957343.72 619019.91 N 70.29211502 W 149.03640921 9434.50 71.38 105.91 4617.73 7320.81 -2046.59 7028.95 1.07 5957319.98 619107.26 N 70.29204640 W 149.03570515 9528.99 71.74 106.23 4647.62 7410.45 -2071.41 7115.08 0.50 5957296.46 619193.75 N 70.29197839 W 149.03500809 9622.90 70.80 106.01 4677.77 7499.38 -2096.10 7200.52 1.03 5957273.04 619279.54 N 70.29191071 W 149.03431666 9712.56 69.86 106.62 4707.95 7583.81 -2119.82 7281.55 1.23 5957250.54 619360.90 N 70.29184571 W 149.03366095 9810.32 71.20 107.39 4740.54 7675.96 -2146.77 7369.69 1.56 5957224.90 619449.42 N 70.29177183 W 149.03294771 9903.52 72.22 107.33 4769.78 7764.43 -2173.18 7454.14 1.10 5957199.76 619534.26 N 70.29169947 W 149.03226425 9997.74 71.56 106.87 4799.07 7853.97 -2199.51 7539.74 0.84 5957174.71 619620.23 N 70.29162730 W 149.03157161 10091.28 71.92 107.12 4828.38 7942.79 -2225.47 7624.69 0.46 5957150.02 619705.55 N 70.29155613 W 149.03088417 10187.52 71.26 106.48 4858.77 8034.09 -2251.87 7712.10 0.93 5957124.93 619793.34 N 70.29148379 W 149.03017679 10283.09 71.68 106.60 4889.15 8124.71 -2277.66 7798.97 0.46 5957100.44 619880.57 N 70.29141307 W 149.02947386 10376.13 72.97 107.01 4917.39 8213.35 -2303.29 7883.83 1.45 5957076.08 619965.80 N 70.29134281 W 149.02878717 10468.68 72.61 105.76 4944.78 8301.75 -2328.23 7968.64 1.35 5957052.41 620050.97 N 70.29127443 W 149.02810085 10562.40 71.95 105.67 4973.30 8391.02 -2352.41 8054.58 0.71 5957029.51 620137.25 N 70.29120812 W 149.02740544 10656.91 72.40 105.51 5002.23 8480.99 -2376.59 8141.24 0.50 5957006.63 620224.25 N 70.29114181 W 149.02670416~ 10751.06 72.55 104.36 5030.59 8570.75 -2399.73 8227.99 1.18 5956984.79 620311.33 N 70.29107834 W 149.02600220 10846.59 72.07 103.83 5059.61 8661.71 -2421.90 8316.26 0.73 5956963.95 620399.91 N 70.29101753 W 149.02528788 10940.90 72.10 103.79 5088.62 8751.37 -2443.32 8403.40 0.05 5956943.83 620487.36 N 70.29095874 W 149.02458270 11035.51 71.20 103.57 5118.41 8841.09 -2464.55 8490.65 0.98 5956923.90 620574.91 N 70.29090045 W 149.02387665 11129.69 71.75 103.53 5148.33 8930.31 -2485.48 8577.47 0.59 5956904.27 620662.02 N 70.29084303 W 149.02317413 11224.14 71.02 103.79 5178.48 9019.73 -2506.61 8664.44 0.82 5956884.44 620749.29 N 70.29078501 W 149.02247031 11317.88 71.29 104.45 5208.76 9108.40 -2528.26 8750.48 0.73 5956864.08 620835.63 N 70.29072561 W 149.02177412 11409.79 71.08 104.70 5238.40 9195.37 -2550.15 8834.68 0.34 5956843.45 620920.14 N 70.29066553 W 149.02109279 11504.36 71.30 105.12 5268.90 9284.87 -2573.18 8921.18 0.48 5956821.71 621006.97 N 70.29060233 W 149.02039281 11597.81 71.28 105.08 5298.87 9373.36 -2596.24 9006.64 0.05 5956799.93 621092.75 N 70.29053906 W 149.01970133 Schlumberger Private W-207 ASP Final Survey.xls Page 4 of 5 5/16/2003-8:34 AM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S EI-W DLS Northing Easting Latitude Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (°/1 DDft) (ftUS) (ftUS) 11690.87 70.96 105.46 5328.98 9461.41 -2619.43 9091.58 0.52 5956778.01 621178.02 N 70.29047542 W 149.01901399 11784.35 71 .44 105.97 5359.11 9549.90 -2643.40 9176.76 0.73 5956755.32 621263.55 N 70.29040966 W 149.01832473 11879.64 71.08 106.10 5389.72 9640.14 -2668.33 9263.49 0.40 5956731.69 621350.63 N 70.29034128 W 149.01762299 11972.77 71.19 106.39 5419.84 9728.26 -2692.98 9348.10 0.32 5956708.30 621435.59 N 70.29027364 W 149.01693840 12066.95 70.75 106.06 5450.55 9817.30 -2717.86 9433.59 0.57 5956684.70 621521.43 N 70.29020539 W 149.01624670 12161.31 70.59 106.45 5481.78 9906.34 -2742.78 9519.07 0.43 5956661.06 621607.26 N 70.29013700 W 149.01555506 12255.68 70.63 106.38 5513.11 9995.35 -2767.93 9604.46 0.08 5956637.18 621693.01 N 70.29006798 W 149.01486417 12299.99 70.54 106.39 5527.84 10037.14 -2779.72 9644.55 0.20 5956625.99 621733.27 N 70.29003564 W 149.01453978 12380.00 70.54 106.39 5554.49 10112.58 -2801.01 9716.92 0.00 5956605.79 621805.95 N 70.28997723 W 149.01395420 .~. -- W-207 ASP Final Survey.xls Schlumberger Private Page 5 of 5 5/16/2003-8:34 AM ~ ~ Q ~ ~ SCRLUMBERGER Drilling and Measurements Survey report Client.............. ... ..: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: polaris Well. . . . . . . . . . . . . . . . . . . . .: W-207i API number........ ..... ..: 50-029-23145-00 Engineer...... ... ...... ..: E. Roux ,- lIG: . . . . . . . . . . . . . . . . . . . . .: Nabors 9ES STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions. ....: Minimum curvature Method for DLS... ........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum. ....... ..: MEAN SEA LEVEL Depth reference.. ........: Driller's Pipe Tally GL above permanent.. ... ..: 52.40 ft KB above permanent. .... ..: N/A - Top Drive DF above permanent.... ...: 80.90 ft ----- Vertical section origin---------------- Latitude (+N/S-) ..... ....: 0.00 ft Departure (+E/W-) ........: 0.00 ft ,;-.., .---- Platform reference point--------------- Latitude (+N/S-).. .......: N 70.29764651 Departure (+E/W-).. ......: W 149.0926037 Azimuth from rotary table to target: 106.33 degrees [(c)2003 Drilling and Measurements IDEAL ID6 1C_10] 11-Apr-2003 09:01:27 Spud date. . . . . . . . . . . . . . . . : Last survey date.. .......: Total accepted surveys...: MD of first survey.......: MD of last survey........: Page 1 of 6 2-Apr-03 11-Apr-03 132 0.00 ft 12380.00 ft ----- Geomagnetic data ---------------------- Magnetic model......... ..: BGGM version 2002 Magnetic date.. ...... ....: 05-Apr-2003 Magnetic field strength..: 1150.43 RCNT Magnetic dec (+E/W-) .....: 25.68 degrees Magnetic dip.. ........ ...: 80.78 degrees ----- MWD survey Reference Reference G......... .....: Reference R..............: Reference Dip............: Tolerance of G.... .......: Tolerance of R...........: Tolerance of Dip.... .....: Criteria --------- 1002.68 mGal 1150.43 RCNT 80.78 degrees (+/-) 2.50 mGal (+/-) 6.00 RCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 25.68 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 25.68 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N)........: No degree: 0.00 Drilling and Measurements SCHLUMBERGER Survey Report 11-Apr-2003 09:01:27 Page 2 of 6 -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP 2 190.59 1.07 143.77 190.59 190.58 1.41 -1.44 1.05 1.78 143.77 0.56 MWD IFR MSA 3 282.46 1.16 140.24 91.87 282.43 2.87 -2.84 2.15 3.57 142.85 0.12 MWD IFR MSA 4 381.40 1.45 137.68 98.94 381.35 4.77 -4.54 3.64 5.82 141.29 0.30 MWD IFR MSA 5 475.60 3.28 126.80 94.20 475.46 8.31 -7.03 6.60 9.64 136.83 1.99 MWD IFR MSA 6 568.98 5.36 117.94 93.38 568.57 15.08 -10.68 12.59 16.51 130.30 2.33 MWD IFR MSA 7 664.45 7.54 115.49 95.47 663.43 25.64 -15.46 22.18 27.04 124.88 2.30 MWD IFR MSA 8 760.05 9.14 109.68 95.60 758.02 39.41 -20.72 35.00 40.67 120.63 1.89 MWD IFR MSA 9 854.45 10.89 106.48 94.40 850.98 55.81 -25.77 50.61 56.79 116.99 1.94 MWD IFR MSA 10 949.38 12.90 102.04 94.93 943.87 75.35 -30.53 69.57 75.98 113.69 2.32 MWD IFR MSA 11 1045.03 15.41 99.52 95.65 1036.61 98.62 -34.86 92.55 98.90 110.64 2.70 MWD I FR MSA 12 1138.63 17.59 98.32 93.60 1126.35 124.98 -38.96 118.81 125.04 108.16 2.36 MWD IFR MSA 13 1233.25 19.19 95.28 94.62 1216.13 154.40 -42.46 148.45 154.40 105.96 1.97 MWD IFR MSA 14 1329.24 20.08 98.11 95.99 1306.54 186.19 -46.24 180.47 186.30 104.37 1.36 MWD IFR MSA 15 1422.43 23.81 100.17 93.19 1392.97 220.74 -51.82 214.84 221.00 103.56 4.09 MWD IFR MSA 16 1517.70 25.40 99.10 95.27 1479.58 260.13 -58.45 253.94 260.58 102.96 1.73 MWD IFR MSA 17 1611.50 28.48 99.37 93.80 1563.20 302.30 -65.27 295.88 303.00 102.44 3.29 MWD IFR MSA 18 1707.10 30.13 96.82 95.60 1646.56 348.60 -71.83 342.20 349.66 101.86 2.16 MWD IFR MSA 19 1801.43 31.56 97.65 94.33 1727.55 396.35 -77.93 390.18 397.89 101.30 1.58 MWD IFR MSA 20 1894.15 32.45 100.69 92.72 1806.18 445.10 -85.78 438.68 446.98 101.06 1.98 MWD IFR MSA /~- 21 1989.07 35.78 103.18 94.92 1884.76 498.16 -96.83 490.73 500.20 101.16 3.80 MWD IFR MSA 22 2082.22 37.20 102.19 93.15 1959.65 553.44 -108.99 544.78 555.57 101.31 1.65 MWD IFR MSA 23 2176.18 40.25 101.02 93.96 2032.94 612.01 -120.79 602.35 614.34 101.34 3.34 MWD IFR MSA 24 2271.30 39.07 100.91 95.12 2106.17 672.45 -132.34 661.95 675.05 101.31 1.24 MWD IFR MSA 25 2365.36 41.43 102.81 94.06 2177.95 733.03 -144.85 721.41 735.81 101.35 2.83 MWD IFR MSA 26 2458.98- 42.19 102.65 93.62 2247.73 795.32 --158.60 782.29 798.20 101.46 0.82 MWD IFR MSA 27 2553.93 47.49 102.98 94.95 2315.04 862.13 -173.46 847.55 865.11 101.57 5.59 MWD IFR MSA 28 2645.96 50.96 102.77 92.03 2375.13 931.68 -188.98 915.48 934.78 101.66 3.77 MWD I FR MSA 29 2738.81 53.44 102.76 92.85 2432.04 1004.90 -205.19 987.02 1008.13 101.74 2.67 MWD IFR MSA 30 2833.34 54.88 105.26 94.53 2487.39 1081.46 -223.75 1061.36 1084.69 101.90 2.63 MWD IFR MSA Drilling and Measurements SCHLUMBERGER Survey Report 11-Apr-2003 09:01:27 Page 3 of 6 -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 2927.41 60.20 105.40 94.07 2537.86 1160.79 -244.73 1137.88 1163.90 102.14 5.66 MWD IFR MSA 32 3023.27 62.59 105.79 95.86 2583.75 1244.93 -267.36 1218.94 1247.91 102.37 2.52 MWD IFR MSA 33 3113.70 64.93 106.91 90.43 2623.73 1326.04 -290.20 1296.76 1328.83 102.61 2.82 MWD IFR MSA 34 3209.92 69.55 106.56 96.22 2660.95 1414.74 -315.73 1381.70 1417.32 102.87 4.81 MWD IFR MSA 35 3304.24 71.18 105.63 94.32 2692.64 1503.57 -340.36 1467.06 1506.02 103.06 1.96 MWD IFR MSA ~. 36 3398.61 72.41 105.45 94.37 2722.12 1593.21 -364.37 1553.42 1595.58 103.20 1.32 MWD IFR MSA 37 3492.76 73.51 105.62 94.15 2749.71 1683.21 -388.48 1640.15 1685.53 103.33 1.18 MWD IFR MSA 38 3586.55 72.12 104.93 93.79 2777.42 1772.80 -412.09 1726.58 1775.08 103.42 1.64 MWD IFR MSA 39 3680.06 72.92 105.63 93.51 2805.51 1861.97 -435.60 1812.62 1864.23 103.51 1.11 MWD IFR MSA 40 3774.59 72.71 105.45 94.53 2833.44 1952.27 -459.79 1899.63 1954.48 103.61 0.29 MWD IFR MSA 41 3868.24 72.31 104.87 93.65 2861.59 2041.57 -483.15 1985.84 2043.77 103.67 0.73 MWD IFR MSA 42 3961.35 71.70 104.81 93.11 2890.35 2130.10 -505.83 2071.44 2132.31 103.72 0.66 MWD IFR MSA 43 4053.46 72.08 104.79 92.11 2918.98 2217.62 -528.19 2156.08 2219.84 103.77 0.41 MWD IFR MSA 44 4150.46 71.06 106.84 97.00 2949.65 2309.63 -553.27 2244.62 2311.80 103.85 2.26 MWD IFR MSA 45 4244.02 73.26 107.17 93.56 2978.31 2398.68 -579.31 2329.78 2400.73 103.96 2.38 MWD IFR MSA 46 4339.06 72.33 107.15 95.04 3006.42 2489.46 -606.10 2416.53 2491.38 104.08 0.98 MWD IFR MSA 47 4429.85 71.63 106.84 90.79 3034.51 2575.79 -631.33 2499.09 2577.60 104.18 0.84 MWD IFR MSA 48 4527.05 73.04 106.74 97.20 3064.01 2668.40 -658.09 2587.76 2670.13 104.27 1.45 MWD IFR MSA 49 4622.67 72.20 106.67 95.62 3092.57 2759.65 -684.32 2675.16 2761.30 104.35 0.88 MWD IFR MSA 50 4718.31 71.39 107.19 95.64 3122.45 2850.50 -710.77 2762.08 2852.06 104.43 0.99 MWD I FR MSA ~ 51 4811.52 72.68 106.69 93.21 3151.20 2939.15 -736.61 2846.89 2940.64 104.51 1.48 MWD IFR MSA 52 4905.96 72.34 106.44 94.44 3179.58 3029.23 -762.29 2933.23 3030.66 104.57 0.44 MWD IFR MSA 53 4999.86 70.80 106.53 93.90 3209.26 3118.31 -787.56 3018.65 3119.69 104.62 1.64 MWD I FR MSA 54 5093.92 70.35 105.91 94.06 3240.55 3207.01 -812.34 3103.82 3208.36 104.67 0.78 MWD IFR MSA 55 5189.56 71.56 106.95 95.64 3271.75 3297.41 -837.91 3190.53 3298.72 104.72 1.63 MWD IFR MSA 56 5285.22 71.68 106.70 95.66 3301.92 3388.19 -864.19 3277.42 3389'.44 104.77 0.28 MWD IFR MSA 57 5379.25 71.59 106.34 94.03 3331.54 3477.43 -889.57 3362.98 3478.64 104.82 0.38 MWD IFR MSA 58 5473.74 70.71 106.11 94.49 3362.07 3566.85 -914.55 3448.84 3568.04 104.85 0.96 MWD IFR MSA 59 5568.79 72.19 106.59 95.05 3392.31 3656.96 -939.92 3535.31 3658.12 104.89 1.63 MWD IFR MSA 60 5660.85 72.61 105.39 92.06 3420.15 3744.71 -964.09 3619.66 3745.85 104.91 1.32 MWD IFR MSA Drilling and Measurements SCHLUMBERGER Survey Report 11-Apr-2003 09:01:27 Page 4 of 6 -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 5755.69 71.95 108.57 94.84 3449.02 3835.03 -990.46 3706.05 3836.12 104.96 3.27 MWD IFR MSA 62 5849.56 71.29 108.02 93.87 3478.62 3924.06 -1018.43 3790.63 3925.05 105.04 0.90 MWD IFR MSA 63 5943.20 70.47 107.61 93.64 3509.29 4012.50 -1045.50 3874.86 4013.43 105.10 0.97 MWD IFR MSA 64 6037.47 71.20 107.44 94.27 3540.25 4101.52 -1072.31 3959.77 4102.39 105.15 0.78 MWD I FR MSA 65 6132.49 71.44 106.16 95.02 3570.69 4191.53 -1098.32 4045.94 4192.36 105.19 1.31 MWD IFR MSA -- 66 6227.47 70.59 106.85 94.98 3601.59 4281.34 -1123.82 4132.05 4282.15 105.22 1.13 MWD IFR MSA 67 6323.50 71.43 109.05 96.03 3632.84 4372.10 -1151.81 4218.43 4372.85 105.27 2.34 MWD IFR MSA 68 6417.48 71.46 108.34 93.98 3662.74 4461.12 -1180.37 4302.82 4461.78 105.34 0.72 MWD IFR MSA 69 6511.48 70.68 109.34 94.00 3693.24 4549.95 -1209.07 4386.97 4550.54 105.41 1.30 MWD IFR MSA 70 6606.35 72.13 110.34 94.87 3723.49 4639.69 -1239.58 4471.55 4640.19 105.49 1.83 MWD IFR MSA 71 6700.79 71.86 109.47 94.44 3752.68 4729.33 -1270.16 4556.00 4729.74 105.58 0.92 MWD IFR MSA 72 6794.92 70.56 110.02 94.13 3783.00 4818.29 -1300.27 4639.87 4818.62 105.65 1.49 MWD I FR MSA 73 6887.88 72.01 110.26 92.96 3812.83 4906.13 -1330.58 4722.53 4906.40 105.74 1.58 MWD IFR MSA 74 6981.69 71.64 109.60 93.81 3842.09 4995.09 -1360.96 4806.32 4995.29 105.81 0.78 MWD IFR MSA 75 7075.03 70.66 109.37 93.34 3872.25 5083.28 -1390.43 4889.59 5083.45 105.87 1.08 MWD IFR MSA 76 7169.00 71.38 110.37 93.97 3902.81 5171.97 -1420.62 4973.17 5172.09 105.94 1.26 MWD IFR MSA 77 7263.79 71.34 110.49 94.79 3933.11 5261.56 -1451.97 5057.34 5261.64 106.02 0.14 MWD IFR MSA 78 7358.11 72.40 109.84 94.32 3962.46 5351.00 -1482.87 5141.48 5351.05 106.09 1.30 MWD IFR MSA 79 7451.10 72.97 107.38 92.99 3990.14 5439.70 -1511.19 5225.61 5439.73 106.13 2.60 MWD IFR MSA 80 7545.85 73.08 107.53 94.75 4017.80 5530.30 -1538.37 5312.05 5530.33 106.15 0.19 MWD IFR MSA _r-~. 81 7640.53 71.62 106.02 94.68 4046.51 5620.51 -1564.42 5398.43 5620.54 106.16 2.17 MWD IFR MSA 82 7734.74 71.11 105.85 94.21 4076.61 5709.78 -1588.93 5484.27 5709.81 106.16 0.57 MWD I FR MSA 83 7829.68 71.32 105.96 94.94 4107.18 5799.66 -1613.56 5570.71 5799.69 106.15 0.25 MWD IFR MSA 84 7923.65 71.25 106.10 93.97 4137.33 5888.66 -1638.13 5656.25 5888.69 106.15 0.16 MWD IFR MSA 85 8019.21 71.07 105.70 95.56 4168.19 5979.10 -1662.91 5743.23 5979.13 106.15 0.44 MWD IFR MSA 86 8114.44~ 70.77 105.17 95.23 4199.32 6069.09 ~1686.86 5829.99 6069.12 106.14 0.61 MWD IFR MSA 87 8206.06 70.05 106.16 91.62 4230.05 6155.39 -1710.17 5913.09 6155.43 106.13 1.29 MWD IFR MSA 88 8300.47 71.11 106.17 94.41 4261.45 6244.43 -1734.96 5998.61 6244.47 106.13 1.13 MWD IFR MSA 89 8396.62 70.35 106.53 96.15 4293.18 6335.19 -1760.51 6085.70 6335.23 106.13 0.87 MWD IFR MSA 90 8490.42 72.45 106.60 93.80 4323.10 6424.09 -1785.85 6170.91 6424.12 106.14 2.24 MWD IFR MSA Drilling and Measurements SCHLUMBERGER Survey Report 11-Apr-2003 09:01:27 Page 5 of 6 -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual ( ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 91 8585.54 71.86 107.77 95.12 4352.25 6514.62 -1812.60 6257.41 6514.65 106.15 1.32 MWD IFR MSA 92 8681.00 71.22 108.34 95.46 4382.47 6605.12 -1840.65 6343.50 6605.15 106.18 0.87 MWD IFR MSA 93 8775.77 71.32 108.14 94.77 4412.90 6694.83 -1868.74 6428.74 6694.84 106.21 0.22 MWD IFR MSA 94 8868.41 71.38 107.76 92.64 4442.53 6782.57 -1895.79 6512.24 6782.58 106.23 0.39 MWD IFR MSA 95 8961.81 71.59 106.92 93.40 4472.19 6871.12 -1922.19 6596.78 6871.12 106.25 0.88 MWD IFR MSA /-- 96 9057.38 72.19 105.97 95.57 4501.91 6961.95 -1947.90 6683.90 6961.96 106.25 1.13 MWD IFR MSA 97 9151.01 71.92 105.55 93.63 4530.76 7051.02 -1972.09 6769.62 7051.02 106.24 0.51 MWD IFR MSA 98 9246.08 72.37 106.12 95.07 4559.91 7141.50 -1996.78 6856.68 7141.51 106.24 0.74 MWD IFR MSA 99 9339.24 72.36 106.20 93.16 4588.13 7230.29 -2021.49 6941.95 7230.29 106.24 0.08 MWD IFR MSA 100 9434.50 71.38 105.91 95.26 4617.78 7320.81 -2046.53 7028.95 7320.82 106.23 1.07 MWD IFR MSA 101 9528.99 71.74 106.23 94.49 4647.66 7410.45 -2071.34 7115.09 7410.46 106.23 0.50 MWD IFR MSA 102 9622.90 70.80 106.01 93.91 4677.82 7499.39 -2096.04 7200.53 7499.40 106.23 1.03 MWD IFR MSA 103 9712.56 69.86 106.62 89.66 4708.00 7583.81 -2119.75 7281.55 7583.82 106.23 1.23 MWD I FR MSA 104 9810.32 71.20 107.39 97.76 4740.58 7675.97 -2146.71 7369.69 7675.98 106.24 1.56 MWD IFR MSA 105 9903.52 72.22 107.33 93.20 4769.83 7764.45 -2173.11 7454.15 7764.46 106.25 1.10 MWD IFR MSA 106 9997.74 71.56 106.87 94.22 4799.12 7853.99 -2199.45 7539.74 7854.00 106.26 0.84 MWD IFR MSA 107 10091.28 71.92 107.12 93.54 4828.43 7942.82 -2225.41 7624.69 7942.82 106.27 0.46 MWD I FR MSA 108 10187.52 71.26 106.48 96.24 4858.83 8034.12 -2251.80 7712.11 8034.13 106.28 0.94 MWD IFR MSA 109 10283.09 71.68 106.60 95.57 4889.21 8124.74 -2277.60 7798.97 8124.74 106.28 0.47 MWD I FR MSA 110 10376.13 72.97 107.01 93.04 4917.46 8213.38 -2303.23 7883.83 8213.38 106.29 1.45 MWD IFR MSA ,J~ 111 10468.68 72.61 105.76 92.55 4944.84 8301.78 -2328.17 7968.64 8301.78 106.29 1.35 MWD IFR MSA 112 10562.40 71.95 105.67 93.72 4973.37 8391.05 -2352.35 8054.58 8391.05 106.28 0.71 MWD IFR MSA 113 10656.91 72.40 105.51 94.51 5002.30 8481.02 -2376.52 8141.24 8481.02 106.27 0.51 MWD IFR MSA 114 10751.06 72.55 104.36 94.15 5030.65 8570.77 -2399.65 8227.99 8570.77 106.26 1.17 MWD IFR MSA 115 10846.59 72.07 103.83 95.53 5059.68 8661.71 -2421.81 8316.26 8661.72 106.24 0.73 MWD IFR MSA 116 10940.90 72.10 103.79 94.31 5088.69 8751.36 -2443.24 8403.41 875'1.38 106.21 0.05 MWD IFR MSA 117 11035.51 71.20 103.57 94.61 5118.47 8841.06 -2464.47 8490.66 8841.09 106.19 0.98 MWD IFR MSA 118 11129.69 71.75 103.53 94.18 5148.40 8930.26 -2485.40 8577.47 8930.30 106.16 0.59 MWD IFR MSA 119 11224.14 71.02 103.79 94.45 5178.55 9019.66 -2506.53 8664.44 9019.72 106.13 0.83 MWD IFR MSA 120 11317.88 71.29 104.45 93.74 5208.84 9108.31 -2528.17 8750.48 9108.37 106.11 0.72 MWD IFR MSA Drilling and Measurements SCHLUMBERGER Survey Report 11-Apr-2003 09:01:27 Page 6 of 6 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (de g) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 121 11409.79 71.08 104.70 91.91 5238.48 9195.27 -2550.05 8834. '68 9195.34 106.10 0.35 MWD IFR MSA - 122 11504.36 71.30 105.12 94.57 5268.98 9284.76 -2573.09 8921.18 9284.84 106.09 0.48 MWD IFR MSA - 123 11597.81 71.28 105.08 93.45 5298.97 9373.24 -2596.14 9006.63 9373.33 106.08 0.04 MWD IFR MSA - 124 11690.87 70.96 105.46 93.06 5329.08 9461.28 -2619.33 9091.58 9461.38 106.07 0.52 MWD IFR MSA - 125 11784.35 71.44 105.97 93.48 5359.21 9549.77 -2643.30 9176.76 9549.87 106.07 0.72 MWD IFR MSA r--. 126 11879.64 71.08 106.10 95.29 5389.83 9640.00 -2668.23 9263.48 9640.10 106.07 0.39 MWD IFR MSA 127 11972.77 71.19 106.39 93.13 5419.95 9728.13 -2692.88 9348.09 9728.23 106.07 0.32 MWD IFR MSA - 128 12066.95 70.75 106.06 94.18 5450.66 9817.16 -2717.76 9433.58 9817.26 106.07 0.57 MWD IFR MSA - 129 12161.31 70.59 106.45 94.36 5481.89 9906.20 -2742.68 9519.06 9906.30 106.07 0.43 MWD IFR MSA - 130 12255.68 70.63 106.38 94.37 5513.23 9995.21 -2767.83 9604.45 9995.31 106.08 0.08 MWD IFR MSA 131 12299.99 70.54 106.39 44.31 5527.96 10037.00 -2779.62 9644.54 10037.10 106.08 0.18 MWD IFR MSA 132 12380.00 70.54 106.39 80.01 5554.62 10112.44 -2800.91 9716.91 10112.54 106.08 0.00 Projected to TD [(c)2003 Drilling and Measurements IDEAL ID6_1C_10] /'-.. ) '" , ao 5 ~O(¡9 MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Well No W-207i I nstallation/Rig Nabors 9ES Data Surveys Received By: ~ ~A) LWD Log Delivery V1.1, Dec '97 Dispatched To: Lisa Weepie Date Dispatche 17 -Apr-03 Dispatched By: Nate Rose No Of Prints No of Floppies 2 REceIVE :> M:\Y 052003 Alastta on & Gas Cons. Com1lileion Anchorage Please sign and return to: James H. Johnson BP Exploration (Alaska) Inc. Petrotechnical Data Center (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907-564-4005 e-mail address:johnsojh@bp.com ([J ~-" f&\ ~ -þ c~ .. /1\... I..: .L r.:;-, ---:::.1 LJ \,:::',1 ...r ) /Æ ~JÆ~ ~~IÆ AI,JiSIiA. OIL AND GAS CONSERVATION COMMISSION Lowell Crane Senior Drilling Engineer BP Exploration (Alaska) Inc. .P. O. Box 196612 Anchorage, Alaska 99519-6612 ) FRANK H. MURKOWSK/, GOVERNOR 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Pnldhoe Bay Unit W -207i BP Exploration (Alaska) Inc. Permit No: 203-049 Surface Location: 4285'NSL, 1186' WEL, SEC. 21, TI1N, RI2E, UM BottOlllhole Location: 1431' NSL, 3245' EWL, SEC. 23, TI1N, RI2E, UM Dear Mr. Crane: Enclosed is the approved application for permit to drill the above referenced service well. This penllit to drill does not exelllpt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required penllits and approvals have been issued. In addition, the COlllmission reserves the right to withdraw the penllit 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 COlllply 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 pemlit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Comn1Íssion to witness any required test. Contact the Comlllission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, tE:-~ ~t- Randy Ruedrich ~ Commissioner BY ORDER OF THE COMMISSION DATED thiG:..':2 day of March, 2002 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~6A- '3/zt;; !2({;.;r3 12. Distance to nearest property line 13. Distance to nearest well / ADL 028264,1431' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 450' MD Maximum Hole Angle 18. Casing ~rogram Specifications Size Casina Weiaht Grade Couclina 20" x 34" 215.5# A53 Welded 9-5/8" 40# L-80 BTC 7" 26# L-80 BTC-M Hole 48" 12-1/4" 8-3/4" J'~ STATE OF ALASKA ') ALASKfc\ IL AND GAS CONSERVATION COMMlclSION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test 0 Development Oil II Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan KBE = 80.9' Prudhoe Bay Field I Polaris 6. Property Designation Pool (Undefined) ADL 047451 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number W-207i ./" Number 2S100302630-277 9. Approximate sptJtfgàte øSí2à/~ Amount $200,000.00 14. Number ~s in property 15. Proppsed depth (MD and TVD) 2560 /12429' MD I 55781 TVD o 17. Anticipated pressure {s~ 20 AAC 25.035 (e) (2)} 72 Maximum surface 1814 psig, At total depth (TVD) 5040' I 2318 psig Setting Depth Top Bottom MD TVD MD TVD 29' 291 1091 109' 29' 29' 4874' 3191' 291 29' 124291 5578' 11. Type Bond (See 20 AAC 25.025) 1 a. Type of work II Drill 0 Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface x = 612049, Y = 5959261 4285' NSL, 1186' WEL, SEC. 21, T11 N, R12E, UM At top of productive intelVal x = 620460, Y = 5956950 1843' NSL, 19041 EWL, SEC. 23, T11 N, R12E, UM At total depth x = 621808, Y = 5956560 1431' NSL, 3245' EWL, SEC. 23, T11N, R12E, UM Lenath 80' 4845' 12400' Quantity of Cement (include staae data) 260 sx Arctic Set (Approx.) 734 sx PF IL', 296 sx Class 'G' 549 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report II 20 AAC 25.050 Requirements Contact Engineer Name/Number: Micha~rlriolo, 564-5774 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that, the for~~9jríg is true ~~orrect to the best of my ~nowl~~ge . Signed Lowell cranA~ ~ _ Title Semor Dnlllng Engineer Date ]-2 'j-" 03 V ,Cørnmis.sionU,e()nly Permit Number API Number ~pro~a7Date See cover letter 2a~~ - ð 7' T 50-02. 7 - 2.. .1/ ~ S () J U( DJ fO~. ther requirements Conditions of Approval: Samples Required 0 Yes .œ;I No Mud L g Required Yes 181 No Hydrogen Sulfide Measures 0 Yes ßa No Directional SUlVey Required 'SIes 0 No Requir~d W~:>rking Pressure for BOPE .0 2K 0 3K 0 4K 0 5K ,0 10K 0 15K . 0 3.5K psi for CTU Other: ~<>t- -gop¡;- to 'fOOD p~.. ,vtI..T) tk-\..t~(..(A.[iJ.:1ICj ~"''(''1.N.d. ~ b~orderof IJ :;:>h t Approved By . f~~ Commissioner the commission Date ZJ}~ OJ Form 10-401 Rev. 12-01-85 Submit In Triplicate ", ) Greater prUdhr""fay Polaris W·207i Permit Well Plan SUmmary IWell-Narne·:···lw~207i . "' . ., '1 ".-: ,:.-' :., '., 1 Type of Well (producer or injector): I USH Injector Su rface Location: 9961 FNL, 1,1861 FEL, Sec. 21, T11 N, R12E X = 61 Y = /' 3,431' FNL, 3,3751 FEL, Sec. 23, T11 N, R12E X = 620,46Ö Y = 5,956,950 Z = 5,030' TVDss 3,8481 FNL, 2,0351 FEL, Sec. 23, T11 N, R12E X = 621,807.70 Y = 5,956,559.90 Z = 5,497' TVDss W-207i Target Start: W·207i Target End: 1 AFE Number: I PLD5M1065 1 Rig: I Nabors 9ES /" I Estimated Start Date: I March 28m 20031 1 Operating days to complete: 117.70 MD 112,429' I I TVDrkb: TD I 5,578' I I Max Inc. I 72° I I KBE I 80.90' Well Design: USH Grassroots Schrader Injector. 4- Y2" TCII Completion. Current Well Information General Well Name: API Number: Well Type: Current Status: BHP: BHT: W -207i 50-029- ????? Development - Polaris Schrader Injector New well, 20" X 34" insulated conductor 2,318 psi @ 5,040' TVDss (8.8 ppg EMW). Normal pressure gradient. 100°F @ 5,040' TVDss Estimated Mechanical Condition W-207i: Nabors 9ES: Conductor: Cellar Box above MSL = 52.4' KB / MSL = 28.5' 20" X 34", 215.5Ib/ft, A53 ERW set at 109' RKB Target Estimates Estimated Reserves: 1,946 mstb 1 Expected 12 month avg: 260 bopd (from W-203 ML) , Fi nal 3/25/03 Materials Needed Surface Casing: Intermediate Casing: L-80 Completion: ) 4,880' 1 each 1 each 25 each 1 assembly 1 each 1 lot 12,450' 1 each 95 each 2 lots 3 each 2 each 11 ,400' 1 each 1 each 1 each 2 each 1 each 1 each 1 each 1 each 1 each Drillina Proaram Overview Surface and Anti-Collision Issues Greater prudh"'-ray Polaris W-207i Permit 9-%", 40#, L-80 BTC Casing 9-%", BTC Float Shoe and Float Collar 9-%", 40#, BTC Type TAM Port Collar 9-%" x 12 %" Bow Spring Centralizers FMC 11" 5m Gen 5 Wellhead System 9-%" TAM Port Collar 9-%" casing pups 5', 10',20'. 7" 26# L-80 BTC-M Casing 7" BTC-M Float Shoe and Float Collar 7" x 8%" Rigid Straight Blade Centralizers 7" casing pups 5', 10', 20' 7" RA Tag 7" 26# L-80 BTC-M Casing Short Joint 4 Y2" 12.75 Ib/tt, L-80, TCII tubing Baker PRM Production Packer 7" X 4- Y2" Baker S-3 Production Packer 7" X 4- Y2" Halliburton RN-Nipple (3.688" 10 with 3.456" no go) Halliburton X-Nipple (3.813" 10) Halliburton AVA Sleeve (3.75" 10 bore, 3.70" no go) 11" X 4- Y2" FMC tubing hanger 4-1/16", 5m Cameron Tree 4-Y2" x 1" KBG-2 GLM 4- Y2" WLEG Surface Shut-in Wells: No wells need to be shut-in for the rig move on and off W-207i. Close Approach Shut-in Wells: There are NO close approach wells requiring subsurface isolation for this profile. t?1()~~~pp~()~C?~YVell List: Well Name Ctr-Ctr Distance W-212 91.28-ft K241112 299.34-ft Mud Program Reference MD 494.82-ft 10,127.45-ft 12"IA" Surface Hole Mud Properties: Interval I Density (ppg) Initial 8.6 - 8.8 Base Perm 8.8 - 9.6 , Interval TO 9.3 - 9.6 / Funnel vis 300 200 - 300 200 8 %" Intermediate Hole Mud Properties: Interval/ Density (ppg) Funnel vis Initial 8.6 - 9.0 45 - 55 Ugnu I Schrader 9.5 45 - 55 YP 50 - 70 30 - 60 25 - 48 YP 21 - 28 21 - 28 Allowable Deviation 84.00-tt 73.04-ft Precautionary çÇ)mment Use Traveling Cylinder (Gyro) ,,/ Use Traveling Cylinder I Spud - Freshwater Mud (PHPA) Tauo PH Plastic Vis FL 10 - 18 8.5 - 9.5 20 - 45 15 - 20 8 -16 8.5 - 9.5 20 - 40 < 15 9 -14 8.5 - 9.5 14 - 20 < 10 I Freshwater Mud (PHPA) PH: 8.5 - 9.5 Tauo PV API Filtrate MBT 3 - 6 9 - 14 < 5 < 20 3 - 6 11 - 15 < 5 < 20 2 Fi nal Approved -" Greater prudhr"')ay Polaris W-207i Permit ) Formation Markers - , Formation Tops· . ft,TVDss: ::,FtMD' Ft TVD : Pore, psi' . 'EMW (ppgl " Hydrocarbo'ns' .... Base Permafrost 2,000 2,236 2,081 920 8.80 No SV5 1,830 2,022 1,911 842 8.80 No SV4 1,970 2,198 2,051 906 8.80 No SV3 2,500 2,994 2,581 1,150 8.80 No SV2 2,710 3,608 2,791 1,247 8.80 No SVl 3,030 4,621 3,111 1,394 8.80 No UG4 3,390 5,760 3,471 1,559 8.80 No UG4A 3,440 5,918 3,521 1,582 8.80 Maybe - Heavy Oil UG3 3,800 7,058 3,881 1,748 8.80 Maybe - Heavy Oil UGl 4,250 8,482 4,331 1,955 8.80 Top Schrader Bluff/Ma 4,681 Sand 4,600 9,589 2,116 8.80 Yes Mbl 4,665 9,795 4,746 2,146 8.80 No Mb2 4,725 9,985 4,806 2,174 8.80 No ,.... Me 4,775 10,143 4,856 2,197 8.80 No 1.~ Na 4,840 10,349 4,921 2,226 8.80 No Nb 4,875 1 0,460 4,956 2,243 8.80 No Ne 4,935 10,649 5,016 2,270 8.80 No OA 5,040 10,982 5,121 2,318 8.80 No OBa 5,105 11 ,187 5,186 2,340 8.80 Yes OBb 5,150 11,330 5,231 2,355 8.80 Yes OBe 5,190 11 ,456 5,271 2,370 8.80 Yes OBd 5,255 11,662 5,336 2,395 8.80 Yes OBe . Base injection 5,421 interval 5,340 11,931 2,425 8.70 Yes OBf 5,390 10,089 5,471 2,445 8.70 Yes OBf_Base 5,450 12,279 5,531 2,465 8.70 Yes TD 5,530 12,429 5,611 2,490 8.70 CasinglTubing Program 48" 12-~" 8-3,.4" Tubing 20" X 34" 9-%" 7" 4 Y2" 215.5#/ A53 . Welded r 40# L-80 / BTC / 26# L-80 BTC-M 12.75# L-80 TCII 80' 4,845' 12,400' 11 ,371 ' 29' / 29' 29' / 29' 29' / 29' 29' / 29' 1 09' / 109' 4,874' /3,191' 12,429' / 5,578' 11,400' / 5,253' Cement Calculations Casinq Size 9-%-in 40-lb/ft L-80 BTC - Single Stage Basis 1250% excess over gauge hole in permafrost interval, 30% excess over gauge hole below permafrost Total Cement Volume: Tam Port collar located at 1,000' as a contingency for cement to surface Wash 20 bbls CW1 OQ. Spacer 75 bbls of 'scqSified Spacer weighted to 10.20 ppg Lead 543 bbls 34/s'ks) 10.7 Ib/gal Permafrost L cement - 4.44 cuft/sk Tail 61 bbls 29Q-'Sks) 15.8 Ib/gal Class G + adds - 1.17 cuft/sk Temp I BHST =:: ~ "'F from SOR, BHCT 70° F estimated by Halliburton In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. 3 Final Approved ) Greater prudhr-ray Polaris W-207i Permit Casinq Size 17" 26 Ibltt L-80 BTC-M - Single Stage Basis I 30% excess - TOC: 500' MD above the Ma sands (planned Top Ma: 9,589' MD) => 9,100' MD Total Cement Volume: Wash 5 bbls CW100 Spacer 35 bbls of V~',sc ¡fied Spacer (Mud push XL Design) Weighted to 10.2 ppg Tail 113.5 bbls .4 sks) 15.8 Iblgal Class G Slurry - 1.16 cuft/sk with .6% LAP 1, ~35 Ibs/sk S ,er CBL, .50/0 UCS, .05 Isk D-Air~3, .60/0 HR-5 Temp BHST ~ 100° F from SOR, BHCT 80° F estimated by Halliburton 9-%" Casing Centralizer Placement a) Run (25) 9-%" Bow-spring centralizers attached over the collar of each joint of casing from the casing shoe up to 3,874' MD (1,000' MD above the shoe). b) Run 2 Bow-spring centralizers on either side of the TAM Port Collar. c) This centralizer program is subject to change pending actual hole conditions. 7" String Centralizer Placement a) Place 2 centralizers rigid straight blade centralizers back to back at the very bottom of the shoe joint. Do not run any centralizers on the next two full joints. b) With the exception stated above, run one centralizer per joint, floating across the entire joint up to 9,100' MD (500' MD above Ma sand). Zonal isolation with cement is required across the Ma sands. The centralizer program is subject to change pending modeling and hole conditions. Bit Recommendations Surface 12-~" 0' - 2,236' Hughes MXC-1 2x20 1x14 1x12 Surface 12-~" 2,236' - 4,874' Hughes MXC-1 2x20 1 x 14 1x12 Interm. 8-% 4,874' - 12,429' Hycalog DS70N PV 6x14 Survey and Logging Program 12-~" Hole Section: Open Hole: Cased hole: 8-%" Hole Section: Cased Hole: Surface Gyro if needed (have discussion with ODE on photo or E-line Gyro) MWD I GR None MWD I GR I Res I Den I Neu I PWD (Den Neu recorded only) USIT Bond Log Motors and Required Doglegs BHA No. 1&2 Motor Size and Motor Required 9-%" Anadrill A962M3445SP Mud Motor, 1.5° ABH with 12-~" string stabilizer 6-%" Anadrill A675M4570XP Mud motor, with 1.15° ASH with 7.0" string stabilizer Flow Rate 400 - 650 gpm 500 - 600 gpm RPMs 40-60 Required DOQleQs 1.75°/100' initial build 4°/100' final build Hold 72° Tangent 3 60-120 4 Final Approved ') Greater prudh'....,ray Polaris W-207i Permit Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and are capable of handling the maxim~ potential surface pressures. Based upon calculations below, BOP equipment will be tested to 4,000 psi. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. · Production Section- Maximum anticipated BHP: 2,318 psi @ 5,040' TVQss - Schrader Maximum surface pressure: 1,814 psi @ surface / (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · · Planned BOP test pressure: · Planned completion fluid: 4,000 psi (the 7" casing will be tested to 4,000 psi) ~ Estimated 9.2 ppg Brine / 6.8 ppg Diesel Planned" BOPE Test' Pres. 4,000/250 psi Rams & Valves 2,500/250 psi Annular Disposal · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at OS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to OS-04 for injection. Haul all Class I waste to Pad 3 for disposal. 5 Final Approved ) Greater prUdh'--fay Polaris W-207i Permit Drillina Hazards and Continaencies POST THIS NOTICE IN THE DOGHOUSE Well Control ~~) Ä. The Schrader in this fault block is expected to be normal pressured at . .., pg EMW. This pressure is estimated based on offset well pressures and material balance. ' . Hydrates and Shallow gas Ä. Hydrates have not been a significant issue thus far on W-Pad during the recent drilling of W-203, W-211, and W- 212i however there is always a potential. III. Lost Circulation/Breathing Ä. Lost circulation is unlikely. B. We do not expect breathing on this well. IV. Kick Tolerance/Integrity Testing Ä. The 9-%" casing will be cemented to surface. B. The 7" casing will be cemented with 15.8 Ib/gal tail cement to 500' MD above the Ma sand -9,586' MD. C. The Kick Tolerance for the surface casing is 77.5 bbls with 9.2 ppg mud, 11.0 ppg LOT, and an 8.8 ppg pore pressure. If the LOT is less then 11.0 ppg EMW, then the kick tolerance will be < 50 bbls. D. Integrity Testing I. II. V. :::'~¡$*·~Ç>h11?:\ 9-%-in shoe ·"mi~*:..yp':I. Uf:·';iMW'(I~lÃif)::·: 20-ft minimum from 9-%--in shoe LOT 11.0 minimum r Stuck Pipe Ä. We do not expect stuck pipe. B. There could be slight differential sticking issues across the Ugnu. Centralizers will be run to mitigate. VI. Hydrogen Sulfide / Ä. W Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. Water injection on W-Pad was just initiated in late 2001, and H2S levels are expected to remain low until the waterflood matures. Recent H2S data from the pad is as follows: B. Adjacent producers at Surface: a. W-1 0 ppm b. W-15 0 ppm C. Adjacent producers at TD: a. W -203 0 ppm b. W-211 0 ppm D. The maximum level of H2S recently recorded on the pad was under -20 ppm. VII. Faults Ä. One fault is planned to be crossed up in the UGNU after the surface casing shoe. This fault has been crossed on numerous wells and is not expected to cause any drilling problems. The fault details are listed below for reference: Fault #1: 6,934' MD 3,684' TVD 3,603' TVDss Throw: 70' West CONSULT THE W PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 6 Final Approved ) Drill and Complete Procedure Summary Greater Prudhr -1ay Polaris W-207i Permit Pre-Rig Work: 1. A conductor has already been set for W-207i. 2. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the conductor. 3. If necessary, level the pad and prepare location for rig move. 4. Prepare neighboring wells for the rig move and simops production. Rig Operations: 1. MIRU Nabors 9ES. / 2. Nipple up diverter spool and function test diverter if required. PU 5" DP as required and stand back in derrick. ,/' 3. MU 12-%" drilling assembly with MWD/GR and directionally drill surface hole to approximately 4,877' MD. The actual surface hole TD will be +/-100' TVD below the top of the SV1 sands. 4. Run and cement the 9-%", 40.0-lb/ft. surface casing back to surface. A TAM Port collar or stage tool will be run in the /' casing string to allow secondary cementing, in the event cement is not circulated to surface during primary cementing operations. 5. ND diverter spool and NU casing / tubing head. NU BOPE and test to 4,000 psi. /' 6. MU 8-3,4" drilling assembly with MWD/GR/Res/Den/Neu(recorded)/PWD and RIH to fl0;t..c0llar. Test the 9-%" casing to 3,500 psi for 30 minutes. 7. Circulate and condition cement contaminated mud. Displace over to new 9.0 ppg mud 8. Drill new formation to 2 el w 9-%" shoe and perform LOT (minimum 11.0 ppg EMW). 9. Drill ahead to TD at /2.,27 MD, the base of Schrader formation. /' 10. 10. Perform wiper tmr-ifnd condition the hole for casing. POOH laying down the 5" DP. 11. Run and cement the 7" production casing as required to cover all significant hydrocarbon intervals. Displace the casing with perf pill and 9.2 ppg brine during cementing operations and freeze protect the 7" x 9-%" annulus as required. 12. LD the rest of the 5" DP and PU ±11 ,000' of 4" DP as required to DPC perforate while waiting on cement. 13. RU Schlumberger E-line and run a USIT log in the 7" casing. / 14. RU Halliburton and PU 140' of 4-%" Millenium 5 spf perforation assembly with -385' of spacer pups(it may be more economic to pick up 2-%" PAC to space out guns). RIH to PBTD, space out and perforate. 15. PU to above top perf and circulate wellbore, monitor for losses. POOH, LD perforation assembly. 16. MU cleanout assembly with bit and 7" casing scraper, run to bottom and circulate and cleanup any perf debris. Design assembly for rotation. POOH and LD 4" DP and cleanout assembly. /' 17. Run the 4-¥2" 12.75#, L-80 TCII completion with a 7" x 4-%" stacker packer assembly and AVA sleeve. /' 18. Run in the lockdown screws and set the packers. Test the production casing/tubing annulus and tubing to 4,000 psi each. Shear the DCR shear valve. 19. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. 20. Freeze protect the well to -2,200' TVD. Install a VR plug in the 7"x 4-¥2" annulus valve & secure the well. 21. Rig down and move off. Post-Rig Work: 1. R/U Slickline and pull ball and rod / RHC from the tailpipe. 2. Replace the DCR shear valve with a dummy GL V. 3. Tag TD with slickline 4. Pull dummy sleeve in AVA nipple and replace with ported sleeve 7 Final Approved ) Greater prudhr-1ay Polaris W-207i Permit o:mll:llmtlmIWlrmrmlllll.l. "IIIIIII llllIllrl:,ICI::Ulllmnrlllll!ll. -lllllmmlalll'llllllll,mllllm.IICIUII.llrIIUI:rlllllll;.GII:m~IIIIIIII'II :llllrrulll :mmmlllllllmmmllllmIllUllanrIllUlwm!!IIIIIIIlIIlm. .I. _lIImlllll~·"'::~III_ .11. .1..11. _:_II.I~"'·'I"tlm_li~l. _ II.II.t .1. .mrllllmrmlll lllIlmllml:+lII::I.II. .1. --:'III:mmmILIH!:--:~mlm_ _!lmmlllllllll m::,nUIU:I:-:~lmllmll:III:I: lmIW:II:.I,lr Job 1: MIRU Hazards and Contingencies: ~ Ensure the starting head has been welded on the conductor at the right height and there is adequate space to NU the diverter and subsequently the BOP once the rig is spotted (LL on W-212i). ~ Ensure the AOGCC receives 24-hour advance notification of the diverter test and subsequent BOP tests. /' ~ No wells are required to be shut in. ·1:lm:I::_lmIIllDI: :IW:mm~ll,mlmllrl.lll:,acc,IIII:III':ml:1:1'rC::I'mlc:m:nlll:IlIC:lmlll::I':__rl:_mll_ :lnlll~rl,:m:r,-llllm:llllmt_n:ml:mlmClllnln:,mllmrlllmlllm:ctOI:,ItOlmlllt_IIOClt IIOlltll,:CIIIOlmll!llItOllllm:O-I:II-~111111,:UI lomlmIO II_IIIIIt-~mtIOltlnlllumlln:IOIIIIOIO1_lllalll:-I--IIII:llnmmIIIIUlnl_IIIOII:II:lm:-I-tlltla,llmlnl!nIIIOlnlllllmlml:I_:I::I:III~lmlmmlmlmlllm\mll:n:II:I,II:IOOllllllmlll:I:II:tl:~:IOla mllll tllmlIIW~:1:011 Job 2: DriIl12~" Surface Hole Hazards and Contingencies: ~ At W -Pad, no significant surface hole drilling problems have been identified. Minor tight hole has been encountered in the clay sections below the permafrost, some lost circulation thought to be in conjunction with the tight hole, possible packing off has been encountered. ~ Close Approach: No wells are required to be shut in. There are several close tolerance wells in the surface /' interval. Follow the traveling cylinder / no-go plot per established procedures. Should not need to run a gyro. Magnetic interference is expected to be nonexistent. ~ Directional: Every effort should be made to ensure a 'smooth' well profile that will benefit torque / drag in the later hole sections. A graduated build profile is planned. Objective is to keep DLS S1° over planned. ~ Hole Cleaning: Good hole cleaning practices will be critical to the success of the well. Surface rotary speeds should be maximized wherever possible. The BHA is limited to 60 to 80-rpm because of the 1.50 motor bend. Vary flowrates 400-650 GPM to achieve the required directional response. However it will be possible at TO to raise the rotary speed to +1 OO-rpm prior to POOH to run casing. At this time flowrates should be increased to 650 - 700 GPM to increase hole cleaning. ~ Drill Pipe specs: from Premium classification, not New. 5",19.5#,4-%" IF, IG1 ID Collapse Burst Torsional Tensile 1000/0 4.276 8,765 psi 12,526 psi 45,200 Ibs 436,100 Ibs 800/0 3.250(tool joint) 7,012 psi 10,021 psi 36,2001bs 348,880lbs ***Max Recommended MU Torque: 26,800 ft-Ibs ***Min Recommended MU Torque: 25,900 ft-Ibs ~ Tight spots: During short trips, work out any tight spots as they are seen while pulling out of the hole instead of waiting and reaming them out after running back in the hole as this could lead to accidental sidetracking. Consider back-reaming across initial tight spots only if washing does not alleviate the problem. ~ Critical LWD Tools: It is critical for the landing of this hole section to have the GR to pick the base of the SV1 sand. If this tool fails, it will require an immediate trip out of the hole to replace. It is imperative that the surface casing isolates all of the SV1 sands. Job3: Install Surface CasinQ Hazards and Contingencies: ~ Casing to bottom: It is imperative the casing is set in the shale below the SV1 sands to ensure wellbore integrity for the intermediate interval. It may be desirable to stop and roll the mud over half way in the hole to break the gels and reduce surging intensity on the SV sands. This will also help to insure circulation is attained at TO at the desired cementing rates without losses. ~ Casing drift: 9-%" special drift casing is being used (8.835" drift required). Ensure that casing equipment is properly drifted to ensure adequate 10 for the 8-%" bit, Le. float equipment, casing hanger, etc. ~ Cement to surface: A single-stage job will be done on this well using 250% excess in the permafrost and, /' 30% excess below the permafrost. As we will be downsizing the nozzles on the bit this may increase hole' erosion slightly due to the extra nozzle velocity. A TAM Port collar will be placed at 1 ,OOO-ft MD. 8 Final Approved ) Greater prudhr-'Tay Polaris W-207i Permit ~ Losses during cement job: Ät W-Pad lost circulation has been experienced while running and cementing surface casing on past wells. The expected frac gradient for the shale below the SV1 sands is 12.5-lb/gal EMW. Follow the Halliburton recommended pumping rates as they have modeled the expected ECD's during the entire cement job to help mitigate the potential for breaking down the formations. I;·~>.;;;m_....;;_w --I :-!-~:II ::I mmr:mlmmnmlrmlmI11111111111:11:11: :II :1IIlnmlmml'111111__~lmmm:nll:.:II:_:III:-:: ::-II:mrmm,11111'::I:-:::IT-mmlmllmml:mmlrm1~IICII:II:'I:'IIII:II,1IIU'--_'1Inlmmmlllll.III:llrll:,-!IWII.::=::I:II,11111mrllll:mllllll:::IIIIIII::Ulmmllmllll:II-:II---:wmmIII:lTIIlnl::III':'I:,I:III:IIIII:11 Job 4: Drill 8%" Production Hole Hazards and Contingencies: ~ Differential Sticking could be a problem if lost circulation is occurring or if the drill string is left stationary for an extended period or time across the permeable Schrader Sands. ~ LOT: Perto- a LOT (minimum 11.0 ppg EMW to satisfy kick tolerance). KICK TOLERANCE: Based upon the e~écte Schrader reservoir pressure of 8.8 ppg and a 9.2 ppg mud, an 11.0 ppg leak-off will provide just ove~170 b ~. of kick tolerance. Contact Anchorage personnel if LOT is less than 11.0 ppg. Based upon off-Sj " .rHUng data on W-Pad, a minimum leak-off of 12.5 ppg is expected at the 9-%" shoe. ~ 7" casing landing point: The landing point for the 1'1 casing will be determined by depth based on changes in GR/Res curves associated with the base OBf sand. After seeing the base OBf, TD will be picked based on drilling 150' MD past this base. This footage is critical for future wellwork. If tops are coming in 100' or more out from proposed, then conduct a short trip and notify town. A Rigsite Geologist will be required on site to pick casing point. ~ Torque: Modeling indicates that high torque values, in the 14,000 to 15,500-ftlb range can be expected by section TD. Use lubricants as per the MI program. If weight transfer problems are encountered during sliding, attempt to circulate and rotate for a minimum of 2 BU to test if lubricants are truly needed or if the hole is loading up with cuttings. ~ Critical LWD Tools: It is critical to have the GR tool in order to pick the landing point for this hole section. As mentioned above in the landing point discussion, the landing of this well will depend on picking the base OBf sand which will be picked by Gamma Ray. Therefore if we loose the GR tool, we will need to trip for it. ~ Faults: There is one major fault that will be crossed in this hole section: Fault #1 : 6,934' MD 3,684' TVD 3,603' TVDss Throw: 70' West ~ Directional Constraints: It is critical to not let the angle get any higher then planned, due to slickline access requirements. It is critical to design a BHA to minimize inclination walking tendencies to minimize wellbore tortuousity. DLS should be kept :::;10 over planned. Job 6: Install 7" Production Casinq Hazards and Contingencies: ~ Tight hole, packing off and lost circulation have been experienced while running casing though this interval. Good hole cleaning and mud conditioning are required for running this string. ~ Centralization/Differential Sticking: See centralizer strategy under Section 3: Drilling Program Overview. Differential Sticking could be a problem if lost circulation is occurring or if the casing is left stationary for an extended period or time across the permeable sands. Ensure the casing is centralized across any permeable zones if the casing is left stationary while running in the hole. ~ RA Tags: There will need to be 3 RA tags placed in the 7" casing for depth control. Placement strategy is: Pip # 1: Top Ma sand, Pip #2: Top OA sand, Pip #3: 5,220' TVDss. ~ Cement Job: It is imperative to achieve a good cement job on this well due to the water wet OA sands. Good zonal isolation of this sand is imperative to the production success of this well. Therefore reciprocate pipe as long as possible while cementing. A USIT log will be run to confirm the quality of the cement job above the Ma sand. Keep cementing ECD's below 12.5 ppg EMW during the displacement. ~ Mud Requirements: Thin the mud as per Ml's Mud Program. The thinner the mud the better displacement is achieved and the better the cement job will be. Extra time spent circulating is warranted to ensure optimum mud properties and hole cleaning prior to the cement job. 9 Final Approved ) Greater prudh"'-ray Polaris W-207i Permit ~ Franks Casing Fill-up tool: lviake sure that a casing fill up tool is on location prior to PU 711 casing. ~ 7" Casing Specifications: 7", 26#, L-80 BTC 1 000/0 80% ID 6.276 6.151 (drift) Collapse 5,410psi 4,328psi Burst 7,240psi 5,792psi Tensile 667,0001bs 533,6001bs /' ~ TIW Valve: Ensure that a TIW valve with a cross over to 7" BTC casing is on the rig floor ',,,,.,;,\, ,.,.,;):I.,.......",'"',I!,-..-,I;,;,;,I,;».o,.,.. .;,),",I,::-..,.,."....',-~¡¡.,:..I!,',I,I~¡, ¡;MJ,;.~.J,."J:>;)¡.....;,,)¡.,.)¡.,,;)¡o,.....,~...;,;¡I,I~;"."...,' .-,-,r,-',-.-.-',-,-,-,-~;-,-,-.-".-m.-¡,I,r.I,-,-.-.-'mm,-,I,I,:m,lm,l,Immm¡,IJ!m.:mnmm¡.I.I,IAI,~wm.l.l,~~I, ',D.I,!,ID.I;,D,lI.l.W,I,D,I,IJ,I.I!,IJ!,I,I,I,I,Im.:!AA-.IA-,m.-,:n.ln,I.IJJWmmmlJ.m;,-;-'!'.-,I,I,'J,:ml.l.l!¡~),\IJ.I,rA1,I.I,I,I.\I.I,m,I,:.a.:¡:.:!,I'mmm.I',IW,:¡,I,I¡,lmm!,IAI,\'.I,I....,!,IJ',:,U,:,:,I.I,I,I,I)!W¡,I.I.I.I,IAAI.I.I,I,;,m,.!,.'!;;!.I.I,Im,I;,I,:,~',I).I',I,I.:,lpm;m',-,-m!,I.I,IW,lm,l,:.lU',-,I,-,-mmmJ!mm,-,-,-'-'U.-,:/A:.-;¡m,w;,;,¡,\;.11,lmm»m,:.I;,I,-,I¡,I.lmww.oo:C Job 10: DPC Perforate Well Hazards and Contingencies ~ The well will be perforated ±105 psi over-balanced. Ensure all personnel are well briefed on Halliburton's perforating procedures and that all responsibilities are understood. ~ It should be stressed that while picking up and running the perforating string, only essential personnel should be on the rig floor. Normally "essential personnel" will consist of the driller, floorhands, perforating crew and the Halliburton hand. All other personnel will stay off the rig floor and out of the cellar until the perforating string is at least 100-ft below the rotary table. ~ Contact Halliburton to prepare for approximately 140' of 4-%" Millennium charge guns at 6 spf. Exact perforation depths will be provided after reviewing the LWD logs. ~ Be prepared for fluid losses to the formation after perforating. Have ample seawater on location and be prepared with LCM if necessary. Follow the LCM decision tree for "After Perforating". Position guns by tagging PBTD and picking up to the appropriate depth. Reference RP: .:. 'Halliburton DPC Procedure' II-J_:_-I:t~ml:II:--:~I~'nl:I:::I:::II:I:IIII':'lml'll111:n:II_II_I:I:IIII_II__II:::I:_I:__I_:II:-:IIII::-:11::lIr I:lltllll:llnl:n:lm:~:ln:nll::IIIII:ml"lllllr::rc:11:~:I_llr~::nl:::~:_:_II_:I_:I:__:::\'mllmlr:lmlm:1111:__I::II:larc:tm:I:I\n:mlm~IIJI_III\:llt::I'-----:tl:ItlllClan::~!o'III:nlmlrlll\I__::::I:lCrm:ml:lI~m:IIIIC:III:11t_111_1_,lta::-:III,tl:::I:I:llmlr:UClnlln:lllllllnllll:11:_I:---lltll_IIII:I:III\:--:::II:'.mr:nllnUIII:-:~~ 1IIIIIIinilmlml:llllrCimil OH"il Job 12: Run Completion Hazards and Contingencies: ~ Dirty Hole: It is critical to have a clean hole to run this completion in due to the production packer. Take time if deemed necessary to run a GR/JB. If the packer partially prematurely sets, set it all the way and run in and chemical cut and remove the completion. Reference RP: .:. 'Completion Design and Running' RP I ''';- T-WI.; -¡U.II';I.lla..cIT. Job 13: ND/NU/Re/ease RiQ Hazards and Contingencies: ~ Diesel will be used to freeze protect the well. The diesel flash point Is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. 10 Final Approved ) ) W-207i Proposed Completion Cellar Elevation = 52.4' Nabors 9ES RK8 = 80.9' j / EJ TAM Port Collar 11,000' 1 9-5/8",40 lIft, L-80, BTC ~. 14,878' 1 7" Short Joint & RA Tag Top MA-Sand -4,631' TVDss Top OA-Sand -5,040' TVDss -5,220' TVDss TREE: FMC 4-1/16" 5M WELLHEAD: FMC Gen 5 System 11", 5M csg.head wI 7" mandrel hanger & packoff 11" x 11", 5M, tbg spool wI 11" x 4-1/2" tubing hanger 11" X 4-1/16" Adaptor Flange ~ 20" X 34" 215.5 I bItt , A53 ERW Insulated l 114' EJ . [ !", ! ¡: ~ I \ ,f: 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 3,000' TVD Camco gas lift mandrel 4-1/2" x 1" KBG2 I - With DCR Shear Valve pinned to 2,500 3,100' TVD ~ 4-1/2", 12.75 Ib/ft, L-80, TCII Coupling 00: 4.932" OriftllO: 3.833"/3.958" ¡ ~ 4-1/2" 'X' Landing Nipple with 3.813" seal bore. ,) (3 j 3 7" x 4-1~2~0~~~~ ~::~:~r~~~~~~n Packer i :, ..I0Ba sand Perfs: 11,215' -11,225' I~ O,DkiA V A BPI Sleeve with 3.75" Polish Bore, 3.70" No/Go ¡ (with Sleeve installed, 3.30" 10) -, ~¡ =:tS¡ I. I, ~ 7" x 4-1/2" Baker 'S-3' Production Packer 4-1/2" 'RN' Landing Nipple with a 3.688 seal and a 3.456" No-Go 10. 4-1/2" WireLine Entry Guide I I --50' above the OBc sand 11,400' MD æ OBc sand Perfs: 11,445'-11,455' & 11,485'-11,495' ~ ! , ' ,!~i' - - - - = OBd sand Perfs: 11,640'-11,650' & 11,670'-11,680' & 11,700'-11,710 = & 11,730'-11,740' 7", PBTD ~ 7", 26 HIlt, LBO, BTC-Mod - - - - 12,349' MD 12,429' MD / Date 3/18/03 Rev By Comments Mik T Proposed Completion GER,;, .a-11. ."17. .(;NJIt'J' J../JiulJIlt'/.t/3P - . or' I WELL: W-207i API NO: 50-029- ...- +-' Q)::J ~C/) g~ o <1.) N > II ..8 c CO :;:-= _0 ..c.~ ã.g Q) - om (6:::':::: o..¡..: :e <1.) Q)D:: > à) ~[j L.. I- ò -2000 - 0- 2000 ~ - VERTICAL SECTION VIEW Client: Well: Field: Structure: Section At: Date: BP Exploration Alaska W-207 (P7) Prudhoe Bay Unit - WOA W-PAD 106.33 deg March 24, 2003 SehtußlberDer ; KOP Bid 1.5!1oo450 MO 450 TVD : 0.00' 100.~· az 0 deportu.. ~' Bid 2.5/100517 MO 517 TVD : 1.00' 1oQ.OO· az 1 departure ddddddd:t±:t:£:~:::~1:~;;d 7.~· 100.00' az 546 departure èrv4l1OO2363MO 2181 TVD ; . .88' 100.00" az 701 departure j End Cry 3217 Me 2667 rvq 1.58' 107.00' az 1381 depirture 9-ð18- C~ Pt4874 MO 3191 TVD - _1- 7!:.58~1~~00·~~9 ~pa~r~:::- '=d~m5d2022lJO:nJ.f:T:VIL. = = = = - = = = = = 1SfJ4 žf9fflD~5~ Fault Croulng6434 "'0 3684 TVD _ _ _ _ _ 71.58' 107.00' az #39 de.J>8rtura - - - - - ¡m3 2994~0"258fìVI} - j Síl2 3'S08~0 719fìVI} .._ on .... .. . ..... ...~ - - svr462TMfJ31TI woj - 4000 ~ =t¡âfÃ55f1 ~~H'Ttb = _.- UG:J705! MD""3Œt 1Wi - UG18482 MD"" 4ffi n7ri. - ~~~S~d~~~~~~M~~~~i@3&s "~~D~92~ = := . OA T0982MD5i2T1VD 6000 - .......__. ____.... n_ _____..__ ._no _... ..·.._.n.._n...n.n....~.. ',-" ._.n ..n. .._......... _. ¡n. . _. _.___n_ ..... __. ---- - "- - - - - - .__......00__....... .._ __un.....n..n __ u n_ Ba~;Per~ 2236 MO 2081 No ---=:= - - -'- .- ==F _HQJd _A~g~ :I.1 ~8'-: Target : .=J.õ9~Wu~j1jfñiP-=. 71.58' 100.ooi IZ 8123 departure j_ L~"" - ! 'ObI' Bãsel2279"M{}55'TI T\7D --k1 -:-0---- ~ TD/7"CsgPt ,UUj2429MDU557SiW 71.58' 107.00" az 10127 departure t I I t I I -2000 0 2000 4000 6000 8000 10000 12000 Vertical Section Departure at 106.33 deg from (0.0, 0.0). (1 in = 2000 feet) i 12000 t 10000 -- - -6000 -- -4000 ..'n ~ --2000 __L1pI!:.ç~I't_._...._.... i 12429 tot) 5578 TV!) : 71.58' 107.00' 8Z ¡ 28478 9718 E -0 ..nA_u ~ ~--/ .- 2000 True North Mag Dee ( E 25.68° 12000 . 10000 . Schlumberger I 8000 i 6000 EAST »> I 4000 .n~..nn . _____.._ · . · . · . · . · . · . · . · . I I o 2000 «< WEST ___on _ _~ u ....~ u !-¡Old AzJ1t¡{jlf10l.;o-: Fault Ò Fault Crossing 6434 tot) 3684 TV!) , 71.58' 107.00' az 1184 8 4279 E ... ./.__7518 2æ3 E _·_··~·o· . -<J ' ..... I~· Cag Pi 4874 MO ~191 TV!) 71.58' 10t.00· az EndC"'¡ 3217 MÒ 2667 TV!) 71.58' 1107.00' az 2918 i360 E ._. ,_ . u_ n I CN 4/100 2363 MD 2181 TV!) 37.88' 100.00" IZ 1228 694E ~nOldu 2110tot) 1981 TV!) ~7.æ· 100.00" az Ø58 541 E Bid 2.51100 517 MD 517 TV!) 1.00' 100.00' IZ 08 1 E KOP Bid 1.51100 ~ 450 tot) 450 TIiD 0.00' 100.00' az ON 0 E Bid 1.751100 1717 MD 1657 TV!) , 31.00' 100'(10' IZ . 578323E -2000 -6000 - :I: ~ ::> o C/) V -4000 - V V -2000 - 0- ^ ^ ^ :I: ~ a::: o z 2000 - PLAN VIEW Client: BP Exploration Alaska Well: W-207 (P7) Field: Prudhoe Bay Unit - WOA Structure: W-PAD Scale: 1 in = 2000 ft Date: 24-Mar-2003 -2000 0 2000 4000 6000 . · . . . 8000 . õ KBE KOP BId 1.5/100 Bid 2.5/100 Bid 1.75/100 Report Date: Client: Field: Structure / Slot: Well: Borehole: UWIIAPI#: Survey Name / Date: Tort I AHD / DDI/ ERD ratio: Grid Coordinate System: Location LatILong: Location Grid NIE YfX: Grid Convergence Angle: Grid Scale Factor: W-207 Proposed Well Profile - Geodetic Report March 24, 2003 Survey / DLS Computation Method: BP Exploration Alaska Vertical Section Azimuth: Prudhoe Bay Unit - WOA (Drill Pads) /24/3 Vertical SectIon OrIgin: ~w_~22POoA77D/PlanWA-207 pprø~ed 3 TVDrv:.:::==.:: Sea Bed / Ground Level Elevation: 50029 Magnetic Declination: W-207 (P7) 1 March 24, 2003 Total Field Strength: 72.025° 110132.36 ft 16.211/1.81E Magnetic Dip: NAD27 Alaska State Planes. Zone 04, US Feet Declination Date: N 70.29764651, W 149.09260374 Magnetic Declination Model: N 5959261.380 ftUS. E 612049.200 ftUS North Reference: +0.85428243° Total Corr Mag North -> True North: 0.99991426 Local Coordinates Referenced To: Schlumberger Minimum Curvature 1 Lubinski 106.330° N 0.000 ft, E 0.000 fI KB 80.9 ft relative to MSL 47.830 ft relative to MSl 25.682° 57520.032 nT 8O.mo April 05. 2003 BGGM 2002 True North +25.682° Well Head 00__'- Grid Coordinates Geographic Coordinates MD I Incl I Azlm I TVD I vSec I NJ-S I EI·W I DLS Northing I Eastlng latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 0.00 0.00 100.00 0.00 0.00 0.00 0.00 0.00 5959261.38 612049.20 N 70.29764651 W 149.09260374 450.00 0.00 100.00 450.00 0.00 0.00 0.00 0.00 5959261.38 612049.20 N 70.29764651 W 149.09260374 500.00 0.75 100.00 500.00 0.33 -0.06 0.32 1.50 5959261.32 612049.52 N 70.29764635 W 149.09260115 516.67 1.00 100.00 516.66 0.58 -0.10 0.57 1.50 5959261.29 612049.77 N 70.29764624 W 149.09259912 600.00 3.08 100.00 599.94 3.53 -0.62 3.50 2.50 5959260.81 612052.71 N 70.29764482 W 149.09257540 700.00 5.58 100.00 699.65 11.04 -1.93 10.94 2.50 5959259.61 612060.17 N 70.29764124 W 149.09251515 800.00 8.08 100.00 798.93 22.86 -3.99 22.65 --zs0 5959257.73 612071.90 N 70.29763561 W 149.09242034 900.00 10.58 100.00 897.60 38.98 -6.81 38.62 2.50 5959255.15 612087.91 N 70.29762791 W 149.09229103 956.67 12.00 100.00 953.16 50.01 -8.74 49.55 2.50 5959253.38 612098.87 N 70.29762264 W 149.09220253 1000.00 13.08 100.00 995.46 59.36 -10.37 58.82 2.50 5959251.89 612108.16 N 70.29761818 W 149.09212747 - / 1100.00 15.58 100.00 1092.34 83.96 -14.67 83.20 2.50 5959247.95 612132.60 N 70.29760643 W 149.09193006 1200.00 18.08 100.00 1188.05 112.74 -19.70 111.71 2.50 5959243.35 612161.18 N 70.29759269 W 149.09169921 1300.00 20.58 100.00 1282.40 145.65 -25.45 144.31 2.50 5959238.09 612193.86 N 70.29757698 W 149.09143525 1400.00 23.08 100.00 1375.22 182.61 -31.90 180.94 2.50 5959232.18 612230.58 N 70.29755936 W 149.09113865 1500.00 25.58 100.00 1466.33 223.56 -39.06 221.51 2.50 5959225.63 612271.25 N 70.29753979 W 149.09081016 1600.00 28.08 100.00 1555.56 268.42 -46.90 265.96 2.50 5959218.45 612315.81 N 70.29751837 W 149.09045024 1700.00 30.58 100.00 1642.73 317.10 -55.40 314.20 2.50 5959210.68 612364.16 N 70.29749515 W 149.09005964 1716.67 31.00 100.00 1657.05 325.58 -56.88 322.60 2.50 5959209.32 612372.58 N 70.29749110 W 149.08999163 Station ID W-207 (P7) report.xls Schlumberger Private Page 1 of 3 3/24/2003-11 :28 AM Grid Coordinates Geographic Coordinates Station ID MD I Inel I Azim TVD VSec NJ-S EI-W I DLS Northing I Eastlng Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0110Oft) (ftUS) (ftUS) 1800.00 32.46 100.00 1727.92 369.14 -64.49 365.76 1.75 5959202.36 612415.85 N 70.29747031 W 149.08964216 1900.00 34.21 100.00 1811.47 423.75 -74.04 419.88 1.75 5959193.61 612470.10 N 70.29744421 W 149.08920396 2000.00 35.96 100.00 1893.30 480.88 -84.02 476.48 1.75 5959184.48 612526.84 N 70.29741694 W 149.08874567 SV5 2021.80 36.34 100.00 1910.90 493.66 -86.25 489.14 1.75 5959182.44 612539.53 N 70.29741084 W 149.08864316 2100.00 37.71 100.00 1973.33 540.46 -94.43 535.51 1.75 5959174.95 612586.01 N 70.29738849 W 149.08826771 End Bid 2109.58 37.88 100.00 1980.90 546.29 -95.44 541.29 1.75 5959174.03 612591.81 N 70.29738572 W 149.08822091 SV4 2198.26 37.88 100.00 2050.90 600.41 -104.90 594.91 0.00 5959165.37 612645.56 N 70.29735987 W 149.08778675 Base Perm 2236.27 37.88 100.00 2080.90 623.60 -108.95 617.89 0.00 5959161.66 612668.59 N 70.29734880 W 149.08760069 Cry 4/100 2362.95 37.88 100.00 2180.90 700.91 -122.46 694.49 0.00 5959149.30 612745.38 N 70.29731187 W 149.08698047 2400.00 39.33 100.48 2209.85 723.89 -126.57 717.24 4.00 5959145.53 612768.18 N 70.29730064 W 149.08679627 ..~ 2500.00 43.25 101.65 2284.98 789.58 -139.25 781.98 4.00 5959133.82 612833.10 N 70.29726598 W 149.08627208 2600.00 47.19 102.65 2355.40 860.36 -154.21 851.35 4.00 5959119.89 612902.68 N 70.29722509 W 149.08571041 2700.00 51.13 103.54 2420.78 935.88 -171.36 925.02 4.00 5959103.84 612976.59 N 70.29717821 W 149.08511392 2800.00 55.08 104.33 2480.80 1015.77 -190.63 1002.62 4.00 5959085.74 613054.46 N 70.29712554 W 149.08448562 2900.00 59.04 105.05 2535.17 1099.64 -211.92 1083.78 -4.00 5959065.66 613135.92 N 70.29706735 W 149.08382850 SV3 2994.03 62.76 105.67 2580.90 1181.78 -233.68 1162.99 4.00 5959045.08 613215.44 N 70.29700787 W 149.08318718 3000.00 62.99 105.71 2583.62 1187.09 -235.12 1168.10 4.00 5959043.72 613220.57 N 70.29700394 W 149.08314580 3100.00 66.95 106.33 2625.91 1277.68 -260.12 1255.18 4.00 5959020.02 613308.01 N 70.29693560 W 149.08244076 3200.00 70.92 106.91 2661.85 1370.98 -286.81 1344.58 4.00 5958994.67 613397.79 N 70.29686264 W 149.08171695 End Cry 3216.68 71.58 107.00 2667.21 1386.77 -291.42 1359.69 4.00 5958990.29 613412.96 N 70.29685004 W 149.08159461 SV2 3608.11 71.58 107.00 2790.90 1758.12 -400.00 1714.83 0.00 5958887.02 613769.65 N 70.29655321 W 149.07871932 SV1 4620.79 71.58 107.00 3110.90 2718.84 -680.93 2633.63 0.00 5958619.85 614692.46 N 70.29578500 W 149.07128089 9-5/8" Csg pt 4873.96 71.58 107.00 3190.90 2959.03 -751.16 2863.33 0.00 5958553.06 614923.16 N 70.29559291 W 149.06942137 UG4 5760.05 71.58 107.00 3470.90 3799.66 -996.98 3667.28 0.00 5958319.27 615730.61 N 70.29492040 W 149.06291333 UG4A 5918.28 71.58 107.00 3520.90 3949.77 -1040.87 3810.85 0.00 5958277.53 615874.81 N 70.29480030 W 149.06175116 Fault Crossing 6434.43 71.58 107.00 3684.00 4439.44 -1184.06 4279.15 0.00 5958141.35 616345.15 N 70.29440843 W 149.05796048 UG3 7057.55 71.58 107.00 3880.90 5030.59 -1356.92 4844.50 0.00 5957976.95 616912.97 N 70.29393525 W 149.05338441 ---/ UG1 8481.62 71.58 107.00 4330.90 6381.60 -1751.97 6136.56 0.00 5957601.24 618210.66 N 70.29285343 W 149.04292698 Top Schrader Ma 9589.24 71.58 107.00 4680.90 7432.39 -2059.24 7141.50 0.00 5957309.02 619219.98 N 70.29201157 W 149.03479415 Mb1 9794.94 71.58 107.00 4745.90 7627.54 -2116.31 7328.13 0.00 5957254.74 619407.42 N 70.29185517 W 149.03328385 Mb2 9984.82 71.58 107.00 4805.90 7807.68 -2168.98 7500.41 0.00 5957204.65 619580.45 N 70.29171081 W 149.03188971 Mc 10143.05 71.58 107.00 4855.90 7957.79 -2212.87 7643.97 0.00 5957162.91 619724.64 N 70.29159051 W 149.03072799 Na 10348.75 71.58 107.00 4920.90 8152.94 -2269.94 7830.60 0.00 5957108.63 619912.08 N 70.29143408 W 149.02921775 Nb 10459.51 71.58 107.00 4955.90 8258.02 -2300.66 7931.10 0.00 5957079.42 620013.02 N 70.29134987 W 149.02840450 Nc 10649.39 71.58 107.00 5015.90 8438.15 -2353.34 8103.37 0.00 5957029.31 620186.04 N 70.29120545 W 149.02701051 Schlumberger Private W-207 (P7) report.xls Page 2 of 3 3/24/2003-11 :28 AM Grid Coordinates Geographic Coordinates I Stat/on ID MD I Inel I Azlm I TVD I VSee NJ·S EI·W DLS Northing I Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) Target 10950.03 71.58 107.00 5110.90 8723.37 -2436.74 8376.14 0.00 5956950.00 620460.00 N 70.29097679 W 149.02480331 OA 10981.67 71.58 107.00 5120.90 8753.39 -2445.52 8404.85 0.00 5956941.65 620488.84 N 70.29095272 W 149.02457100 Oba 11187.37 71.58 107.00 5185.90 8948.54 -2502.58 8591.48 0.00 5956887.38 620676.28 N 70.29079626 W 149.02306086 Obb 11329.78 71.58 107.00 5230.90 9083.64 -2542.09 8720.69 0.00 5956849.81 620806.05 N 70.29068791 W 149.02201535 Obc 11456.37 71.58 107.00 5270.90 9203.73 -2577.20 8835.54 0.00 5956816.41 620921.40 N 70.29059163 W 149.02108605 Obd 11662.07 71.58 107.00 5335.90 9398.88 -2634.27 9022.17 0.00 5956762.14 621108.85 N 70.29043511 W 149.01957597 000 11931.06 71.58 107.00 5420.90 9654.07 -2708.89 9266.23 0.00 5956691.17 621353.97 N 70.29023045 W 149.01760123 Obf 12089.29 71.58 107.00 5470.90 9804.18 -2752.79 9409.79 0.00 5956649.42 621498.16 N 70.29011003 W 149.01643968 12279.14 71.58 107.00 5530.89 9984.29 -2805.45 9582.04 0.00 5956599.34 621671.16 N 70.28996557 W 149.01504601 Obf Base 12279.17 71.58 107.00 5530.90 9984.32 -2805.46 9582.07 0.00 5956599.33 621671.19 N 70.28996554 W 149.01504577 --" TD I 7" Csg Pt 12429.17 71.58 107.00 5578.30 10126.62 -2847.07 9718.16 0.00 5956559.76 621807.87 N 70.28985139 W 149.01394468 Leaal Description: Surface: 4284 FSL 1186 FEL 521 T11N R12E UM Target: 1842 FSL 3376 FEL 523 T11N R12E UM BHL: 1430 FSL 2035 FEL S23 T11N R12E UM Northlna tV) rftUSl 5959261.38 5956950.00 5956559.76 Eastina (X) rftUSl 612049.20 620460.00 621807.87 "- W-207 (P7) report.xls Schlumberger Private Page 3 of3 3/24/2003-11 :28 AM Company: BP Amoco Field: Prudhoe Bay Reference Site: PB W Pad Reference Well: Plan W-207 Reference Wellpath: Plan W-207 NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 28.50 to 12429.17 ft Maximum Radius: 3000.00 ft ') ') BP Exploration Alaska Anticollision Report Date: 3/24/2003 Time: 12:18:22 1 Page: Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well:' Plan W-207, True North W-207 plan 80.9 Reference: Error Model: Scan Method: Error Surface: Db: Sybase Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Well path Date: 2/27/2002 Validated: No Planned From To Survey ft ft 28.50 12429.17 Planned: Plan #7 V1 Casing Points MD ft 4873.96 12429.17 Summary <: Site PB Kup State PB Kup State PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad Version: 8 Toolcode Tool Name MWD+IFR+MS MWD + IFR + Multi Station TV» ft 3190.90 5578.30 Diameter in 9.625 7.000 95/8" 7" Hole Size in Name 12.250 8.750 Offset Wellpath > Reference Offset Ctr-Ctr No-Go Allowable / Well Well path MD MD Distance Area Deviation Warning ft ft ft ft ft K221112 K221112 V1 9196.81 4650.00 500.58 249.76 251.16 Pass: Major Risk K241112 K241112 V1 10127.45 4950.00 299.34 267.78 73.04 Pass: Major Risk Plan W-205 plan W-205 Opt.1 V4 PI 3381.97 3300.00 183.90 95.47 95.48 Pass: Major Risk Plan W-205 plan W-205 Opt.2 VO PI 3574.45 3450.00 233.52 103.47 136.09 Pass: Major Risk Plan W-209 Plan W-209 V3 Plan: W- 2229.71 2200.00 92.36 66.99 42.76 Pass: Major Risk Plan W-213 Plan W-213 V3 Plan: W- 497.64 500.00 125.56 9.93 115.62 Pass: Major Risk Plan W-214 Plan W-214i V4 Plan: W 497.80 500.00 51.16 10.09 41.07 Pass: Major Risk Plan W-215 Plan W-215 V2 Plan: W- 497.81 500.00 30.57 9.90 20.66 Pass: Major Risk W-01 W-01 V1 1501.32 1500.00 176.45 36.22 140.22 Pass: Major Risk W-02 W-02 V4 749.70 750.00 195.73 10.55 185.31 Pass: Major Risk W-02 W-02A V20 750.89 750.00 195.74 10.56 185.31 Pass: Major Risk W-03 W-03 V1 948.97 950.00 229.04 14.84 214.21 Pass: Major Risk W-04 W-04 V1 1039.63 1050.00 264.79 16.25 248.55 Pass: Major Risk W-05 W-05 V1 945.51 950.00 301.73 16.92 284.82 Pass: Major Risk W-15 W-15 V1 588.92 600.00 160.43 9.49 150.94 Pass: Major Risk W-15 W-15A V10 588.92 600.00 160.43 9.49 150.94 Pass: Major Risk W-15 W-15PB1 V6 588.92 600.00 160.43 9.49 150.94 Pass: Major Risk W-15 W-15PB2 V1 588.92 600.00 160.43 9.49 150.94 Pass: Major Risk W-16 W-16 V1 638.00 650.00 194.83 10.17 184.66 Pass: Major Risk W-17 W-17 V1 646.34 650.00 228.11 10.54 217.58 Pass: Major Risk W-18 W-18 V1 694.32 700.00 264.44 11.77 252.67 Pass: Major Risk W-203 W-203 V9 3779.36 3700.00 306.33 107.28 205.34 Pass: Major Risk W-203 W-203L 1 V7 3779.36 3700.00 306.33 107.11 205.52 Pass: Major Risk W-203 W-203L2 V3 3779.36 3700.00 306.33 107.11 205.52 Pass: Major Risk W-211 W-211 V8 1031.39 1100.00 272.02 18.18 256.07 Pass: Major Risk W-212 W-212 V12 494.82 500.00 91.28 7.29 84.00 Pass: Major Risk Field: Prudhoe Bay Site: PB W Pad Well: Plan W -207 WeUpath: Plan W-207 100 AR-" ~ ~~ ~; ~;s Plan W-214 (Plan W-214i) Blan ~-213 (Plan W-213) W-18(W-18) ~'-::i I ~\ 9~'1 ~ ~ ~ Plan W-2IS (Plan W-2IS) 124 9r ~'~ ~rh ~~~ W~~) II I 9'Z '-I ~) :i II:L~ ;¡s¡¡ ~-r~ 1422 1331 "'.1 ~6 -.. , ~:!, ~ ~~ s;: 'V ~ '" 10 I " ~~I', ~~A\ ~ -- "t ~ ~ ~ '/~/ 1!\iY\ I Í,I¡ A<~ . /' .. ,"A,., J~~~\;23 :/~ : r. ~ ~¿ ¿/-~ ,. ", SS4 L \ t / 1) ~~ --P"~'j 8 " T1 ~~~2 ~~-LL 1 Yr '1 ~~, '; ,." "~ l~~ ~ VI"~ v- .N' /1 ~ . I N':/J'J /~ ~ <r ~ ~~7 \ ~~ .;:",,[ 24 ~ Ý-< (\ ~~.) ~~~~ Ply "f\ >.r¡~ 'I w~, (W~') ~ ¡¡¡ ~ ~ ç.1)1 "'J'" Á \, "" ðL&~~ .., \WOZ)~) ~ ~....../_ ~r ..i.e~-::;¡ I '~~, ~ 'C.}f' ^ IX". ~:::-fI< ~ W -04 (W-04) '4..XJ LI"Jt 121- 21o--...c- (fl"'" ~F ~ ~ -L~ ~1( ~/, ~!\\J "7L"j ~~~~' \.~ 180 W-17 (W-17) 3 12 II -294 W-16 (W-16) 200 '<~/ W-212 (W-212) I 17 3 I I I 3 . I S4 -0 W-211 (W-21 í1)7 100 . '-----' 20 / / 200 so -294 Travelling Cylinder Azimuth (TFO+AZI) [deg] va Centre to Centre Separation [IOOftIin] ) Target: W -207 Tgt ) ~ýell: Plan W -207 Based on: Planned Program Vertical Depth: 5030.00 ft below Mean Sea Level Local +N/-S: -2436.73 ft Local +E/-W: 8376.12 ft Longitude: 149°01'29.292 W Radius: 200 ft Site: PB W Pad Drilling Target Conf.: 95% Description: Map Northing: 5956950.00 ft Map Easting : 620460.00 ft Latitude: 70° 17'27 .516N Shape: Circle -2000 -2100 -2200 -2300 -24-00 -2500 -2500 -2l00 -2800 0 CJ CJ CJ CJ C) CJ CJ CJ o ~ CJ C) CJ C) C) CJ C) CJ N (í) -=I- Ln LD r- CD ~ o ~ CD CD CD CD CD CD CD CD / ~ ~ ~ ~ p055031 DATE l12/2003 INV# CK030603D / INVOICE / CREDIT MEMO : ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK99519-6612 'AY: OTHE IRDER IF: DESCRIPTION TOTAL ~ GROSS PERMIT TO DRill ù"7 '\,,().. ?- NATIONAL CITY BANK Ashland, Ohio B P r.-::)'" .,,,... IIIII,", /lIn, II ,,""" (,...,. rll, ~ . f ,I ..,I ",',1 I' . . ", . ~ oJ ,. IUI' '11I,1 ""'" ~onll' "n. DATE March 12;,2003 ALASKA Oil & GAS CONSERVATION COMMISSION 333 W 7TH AVENUE SUITE 100 ANCHORAGE, AK 99501-3539 II· 0 5 SO:} ¡¡II· I: 0 ~ . 2 0 :} B '1 5 I: 0 ¡. 2 ? 8 '1 b II· ). ': DATE 3/12/2003 CHECK NO. 055031 VENDOR DISCOUNT NET 56-389 """"412 No. P 055031 CONSOLIDATED COMMERCIAL ACCOUNT AMOUNT *******$1 00.00******* NOT VA;.:\:~.r:;:~~:~~~:~:.~·::·::::::···- ~.~~:~~.2:~ ;::::::~~~.:~;:~.:~l ...... .~... '.... ....0:....... ...... ...... ...., :~:.::,¿... , '. '. .::~..:: .:.... ::..; ~~ . ::"~.~ ~~ :'/:~'.~..:: ::\~·:·::i::.. :·~:~':~ë\~;/\; ~~~:~?~::~ ~~\::~::\ ::J ') ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (H API number last two (2) digits are between 60-69) "CLUE" The permit is for a. new wellbore segment of existing well Permit No, API No. Production. should continue to be reported as a function' of the original API number. stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for. the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). paOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and to' sample intervals through target zones. WELL PERMIT CHECKLIST COMPANY /fjJ)( ~WELLNAME/¡l?I úJ....¿öþ·PROGRAM: Exp_ Dev_ Redrll_ Re-Enter_ Serv~ Wellboreseg_ FIELD & POOL -I( CL (Ò 6{/r'J /Æ Ò INIT ciAss / - ~ lrvr GEOL AREA .!?70 UNIT# ç; ý'd J G C> '6'"S);,ON/OFF SHORE ~ <I ~ ~ ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . y. N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N~ 5. Well located proper distance from drilling unit boundary. . . . Y N C7 6. Well located proper distance from other wells.. . . . . . . . . Y N . J APPR DATE 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N (),uIJ/ $0/ 3#J j _~¿~ 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N J n v 2j..Zll.ò..::> 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . ~ N (Service Well Only) 13. Well located wlin area & strata authorized by injection order#~ ðQ N (Service Well Only) 14. All wells w/in X mile area of review identified. . . . . . . . .. C!J N ENGINEERING ~ ~ dzf ~ ~ ¡J/lC..-þ OYS q EÇ. -¥--N- tJllt- N N N tUa4~ fflllJ 9· fo PP1 '. N N Mç P 1814 p'; . N v<Þ ~¥-N Al/i.r @N )f,N.A" APPR DATE I;JGIr ~ 1t(1f)~ (Service Well Only) GEOLOGY APPR DATE &3~ (EXpIOrafu;;' Only) 15. Conductor string provided. . . . . . . . . . . . . . . . . . . 16. Surface casing protects all known USDWs. . . . . . . . . . 17. CMT vol adequate to circulate on conductor & surf csg. . . . 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 19. CMT will cover all known productive horizons. . . . . . . . . . 20. Casing designs adequate for C, T, B & permafrost. . . . . . . 21. Adequate tankage or reserve pit.. . . . . . .. . . . . . . . . 22. If a re-drill, has a 10-403 for abandonment been approved. . . 23. Adequate wellbore separation proposed.. . . . . . . . . . .. 24. If diverter required, does it meet regulations. . . . . . . . . . 25. Drilling fluid program schematic & equip list adequate. . . . . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . 27. BOPE press rating appropriate; test to t.f 00 0 psig. 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 29. Work will occur without operation shutdown. . . . . . . . . . . 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . 31. Mechanical condition of wells within AOR verified. . . . . . . . 32. Permit can be issued wlo hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (if off-shore). . . . . .. ...... 36. Contact namelphone for weekly progress reports. ...... "ß-- /,o¡'~ /¿>ð) /- "- AJ'/~ (LF-"¡~~ rv-,...j~~¡- VI" )/ ¡;- ~ ) ß (Pc'-tfrVl -1ft'" ~~.1¡o.r-., 1;"",,, ð«¡£/Y:>,) o ,dv t tf~Þ/o/ ( ( GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER COMMISSIONER: Commentsllnstructions: RP£ TM JH JR SP RR dt<M3 WA '/ MW DS (2)" ! 'C--rjO:3 Rev: 2/25/03 SFD_ \welLpermiCchecklist
