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204-079
e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. d. a. Lt- - 0 '1 ç¡ Well History File Identifier D Two-sided III 11111/11" 111111 Organizing (done) D Rescan Needed /I 1111111111 "" II/ RESCAN ~Olor Items: D Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, No/Type: D Poor Quality Originals: D Other: OVERSIZED (Non-Scannable) D Logs of various kinds: NOTES: BY: ~ Dale (ph /0 k D Other:: Date: + 151 ú1f /1111111111111 "III 151 mP = TOTAL PAGES / b (Count does not include cover sheet) 151 Project Proofing BY: ~ Dale ~ 1110~ Scanning Preparation BY: oft; Production Scanning 11111111111111" III Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) ~YES NO BY: ~ Page Count Matches Number in Scanning Preparation: Date: Ie, Ie¡ /06 If NO in stage 1, page(s) discrepancies were found: Stage 1 YES 151 VVl P NO BY: Maria Date: 151 11111111111111 1111I Scanning is complete at this point unless rescanning is required. ReScanned 11111111111111 "III BY: Maria Date: 151 Comments about this file: Quality Checked 11111111111I111111I 10/6/2005 Well History File Cover Page. doc • • `='.~ ~. ry MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE . , ~~ F:\LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc ~.r-. i r.f !"\ II' L, Itl\ \ r ,_', U lrj . FRANK H. MURKOWSKI, GOVERNOR AItASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Thomas McCarty CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay A-12A BP Exploration (Alaska) Inc. Permit No: 204-079 Surface Location: 1116' SNL, 920' WEL, SEC. 35, T11N, Rl3E, UM Bottomhole Location: 948' NSL, 2291' WEL, SEe. 26, T11N, Rl3E, UM Dear Mr. McCarty: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission t witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 60 (pager). BY ORDER ºVHE COMMISSION DATED thisJ!E day of May, 2004 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. £ ^ p,'''¿ t'\\.lJ.o..J ~ {~~ t.,O G , ~ \I..J ~ I\- s It Ofl-C'Ð4- . STATE OF ALASKA . ALASKA~IL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 o Drill III Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1116' SNL, 920' WEL, SEC. 35, T11 N, R13E, UM Top of Productive Horizon: 153' SNL, 1366' WEL, SEC. 35, T11N, R13E, UM Total Depth: 948' NSL, 2291' WEL, SEC. 26, T11N, R13E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 654447 y- 5949331 Zone- ASP4 16. Deviated Wells: Kickoff Depth t8.Cåsing Prograrn Size Casina Weiaht 3-3/4" x 4-1/4" 3-3/16' x 2-7/8" 6.2# 16.5# 1b. Current Well Class 0 Exploratory III Development Oil 0 Multiple Zone I 0 Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone 5. Bond: 181 Blanket 0 Single Well 11. Well Name and Number: Bond No. 2S100302630-277 PBU A-12A 6. Proposed Depth: 12. Field / Pool(s): /'. MD 10925 TVD 885055 Prudhoe Bay Field / Prudhoe Bay 7. Property Designation: Pool ADL 028286 8. Land Use Permit: 13. Approximate §Pt:'d~te: M<6' 27~04 14. Distance to N'earest Property: 19,000' 9. Acres in Property: 2560 8896 ft 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): 77.4' feet A-11 is 1156' away at 10925' MD 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Maximum Hole Angle 1060 Downhole: 3250 psig Surface: 23700sig Settingp~pth T OD .. ...... ..·...·....i·.···.·... ..····.·.Bbttom Grade CouDlina Lenath MD TVD MD TVD L-80 TCII/ STL 2600' 8325' 8101' 10925' 8850' (C:,f. or saCk.sji (includina staae data) 152 . A 1"1. '(.:' .." I: '( .,... "/'1'_1'\ - -.., Hole 1M AH _ '''1'''1/ V ( ?Of)A 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND R_ - ". Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): I Effective Depth MD (ft): I Effective. Depth TV~ ,..¡,. nk (measured): 9801 9553 None 9757 I 9511 9757 (Approx.)· . Length >:)fZ6· MD .. .. . T\1fi· . . ~tr' ,rot, ""'I Conductor 113' 20" x 30" 8 cu yds Concrete 113' 113' 2677' 13-3/8" 3720 cu ft Arctic Set 2677' 2677' 8804' 9-5/8" 1210 cu ft Class 'G', 130 cu ft AS 8804' 8614' 1489' 7" 396 cu ft Class 'G' 8311' - 9800' 8166' - 9552' PrnnlJr.tinn Liner Perforation Depth MD (ft): 9012' - 9107' 20. Attachments 181 Filing Fee, $100 181 BOP Sketch o Property Plat 0 Diverter Sketch IPerfOration Depth TVD (ft): 8807' - 8896' 181 Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report 181 Drilling Fluid Program 18120 MC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Thomas McCarty, 564-4378 Printed Name Thomas McCarty Title CT Drilling Engineer ~ . I Prepared By Name/Number: Siç¡nature /'~_ ,. ._........--..;. ._.. // ~.c:: 7" Phone 564-4378 Date 5Æ It L/ Terrie Hubble, 564-4628 ..' .. /C __1_' , , . . .. '. . Permit To Drill I API Number: Permit Approval,......L ./ 'Isee cover letter for Number: Z..:: -; ~ - 079150-029-20515-01-00 Date: 01101 D'1 other requirements Conditions of Approval: Samples Required D Yes ~~o Mud Log Required I D Yes ~No _ ~y en Sulfide Measures l8'Yes D No Directional Survey Required )šYes D No Other: \.est BoP- t:;OO (Hi pe,yr c..,O. S/&. 000, Aonroved {[l r ttu... ./' _ _ ~'" ~~i'~g~~~'ON Dale 5í /6 ~ if Form 10-401 ~sed ~003 ¡ ': I' I SÚbmit.n Dup{icate . . BP A-12A Sidetrack Summary of Operatious: Well A-I2 is scheduled for a through tubing sidetrack with SLB/Nordic 1. In preparation for the sidetrack, an existing tubing patch must be pulled, a whipstock set and cement pumped past the whipstock. The sidetrack, A-I2A, will exit ~-ef-the existing 7" liner from a mechanical whipstock. The well targets Zone 4 reserves. A schematic diagram of the proposed sidetrack is attached for reference. The tubing patch will be replaced after the sidetrack. Pre cm Summary (phase 1) 1) No flow test on lA, MIT-IA 2) MIT-OA wi fluid levels 3) Pull 14' long RCP (leak in tubing at 7210', set in 1995, id=2.35") 4) Retrieve reducing nipple at 8342' (2.313" id) 5) Run LDL to confirm no additional leaks in tubing (confirmed leak at 7210') 6) Drift I Run PDS Caliper to assess liner near KOP at 8896' 7) Set mechanical whipstock at approx 8896' (22deg inc) 8) Pump cement past whipstock for P&A CTD Sidetrack Summary (phase 2) 1) MIRU CTD rig. 2) Mill 3.8" window at 8896' md (8621 'TVDss). 3) Drill to 10925' (8850'TVDss) planned TD with MWD/gamma raylResistivity. / 4) Run 3-3/16" x 2-7/8" liner completion. Top ofliner will be at approx 8325' md (8IOI'TVDss) in 4 Yz" tubing tail. / 5) Cement liner, Run MCNL, Perforate. 6) RDMO. Mud Program: · Phase 1: 8.4 ppg seawater · Phase 2: 8.7 ppg used Ao Pro or biozan for milling, new Ao Pro for drilling. Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · A 3-~. L . x 2-7/8" solid cemented liner completion from 8325' to TD at 10925'. The liner cement volume is planned to be øls of 15.8 ppg class G. The top of cement is planned for 8600'md. Perforate liner as per Asset instructions. Parent Well CasinQs Burst (psi) I Collapse (osi\ 9Ys" 47#, L-80 6870 4760 7" 29#, L-80 8160 7020 Sidetrack Casings 3-3/16" 6.2#, L-80, TCII- Prod LNR 8520 7660 2%" 6.5#, L-80, STL - Prod LNR 10570 11170 / Well Control: · BOP diagram is attached. . · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. / · The annular preventer will be tested to 400 psi and 2500 psi. · IA will be double valved at surface due to hole in tubing. Directional · See attached directional plan. Max. planned hole angle is 106 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. · A-I2A will be approximately 1156' ctr-ctr away from well A-II at 10925'md (nearest well) · A-I2A will be approximately 19,000' from the unit boundary, (Prudhoe Bay Unit) . . Logging · MWD Gamma Ray and Resistivity log will be run over all of the open hole section. · A CNL/GRlCCL cased hole log will be run after the liner has been cemented. Hazards /' · A pad j§ considered an H2S pad. The most recent measurement on A-12 was 50ppm in April 2004. All H2S monitoring equipment will be operational. H2S operating procedures will be followed. The highest H2S recording on A pad was 200ppm at well A-43. · Loss circulation is considered medium risk, one fault is predicted in the polygon. Reservoir Pressure · Res. press. is estimated to be 3250 psi at 88oo'ss (7.1 ppg EMW). Max. surface pressure with gas (0.10 psi/ft) to surface is 2370 psi. TREE =1 WB.LHEAD= ACTUA TOR= KB. B.EV = BF. B.EV = KOP= Max Angle = Datum MD = Datum ND= 4" CrN FMe OTIS 77.43' 49.56' 5800' 27 @ 8200' 9087' 8800' SS . .ETY NOTES: WARNING: RADIO TRANSMrrrER IN THER MONITORING SHACK MUST BE TURNED OFF BEFORE ANY WB.L WORK INVOLVING EXA...OSNES CAN BEGIN. CONTACT PADOPERATOR***TX lAX OA COMM. OPERATING PRESSURE OF THE 13· 3/8" ANNULUS MUST NOT EXCEED 2000 PSI (10/04/02 W AlVER)*** A-12 /~ . "4-1/2" CAMeO SSSV NIP, ID = 3.813" I -i 9-5/8" DV PKR I GAS LIFT MANDRa..s ND DEV TYPE VLV LATCH PORT DATE 3004 1 OTIS RA 5670 6 OTIS RA 7268 18 OTIS RA 7926 24 OTIS RA 113-3/8" CSG, 72#, L-80, ID = 12.347" I ST MD 4 3088 3 5754 2 7438 1 8136 Minimum ID = 2.313" @ 8342' 27/8" REDUCED NIPPLE TOPOF7" LNR 1 HLS TBG PATCH 7203'-7217', ID = 2.35" B.EMENTS @ 7205'-7215' -I CHEMICAL INJ. MANDRB. -14-1/2" PARKER X NIP, ID = 3.813" I -ITBG SEAL ASSY I -19-5/8" x 4-112" BKR S-3 PKR, ID = 4.75" 1 8311' -14-1/2" OTIS X NIP, ID = 3.813" 8342' 4-1/2" XN NIPW/2-7/8" REDUCING NIP, ID = 2.313" 14-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" 1 8373' 8373' 8368' -14-1/2" TBG TAIL, ID = 3.958"1 H B.MD- TT LOGGED 02/17/95 I 19-5/8" CSG, 47#, L-80, ID = 8.681" I ÆRFORA TION SUMMARY REF LOG: SWS BHCS ON 10/30/80 ANGLEATTOPÆRF: 21 @ 8897' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8897-8924 S 08/18/91 3-3/8" 4 9012-9020 0 09/14/90 3-3/8" 4 9027-9107 0 09/14/90 3-1/8" 4 9108-9132 S 08/30/90 3-1/8" 4 9137-9144 S 08/30/90 3-1/8" 4 9149-9182 S 08/30/90 9067' -I MARKER JOINT I PBTDI FISH - (2) 3-1/2" SPINNER BLADES ElL (10/17/02) I 7" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" 9800' DATE 01/04/80 06/01/90 01/30/01 02/27/01 05/18/01 10/04/02 REV BY COMMENTS ORIGINAL COMA...ETION RWO SIS-MH CONVERTED TO CANVAS SIS-MD FINAL RN/KAK CORRECTIONS BIINKAK WANER SAFETY NOTE PRUDHOE BA Y UNIT WB.L: A-12 ÆRMITNo: 1801170 API No: 50-029-20515-00 SEC 35, T11 N, R13E DA TE REV BY 10/17/02 DA V /KK FISH COMMENTS BP Exploration (Alas ka) NOTES: WARNING: RA DIO TRANSMITTER IN MONITORING SHACK MUST BE TURNED OFF BEFOREANY WELL WORK INVOLVING EXPLOSIVES CAN BEGIN. CONTACT PAD OPERA TOR.***T X IA X OA COMM. OPERATING PRESSURE OF THE 13- 3/8" ANNULUS MUST NOT EXCEED 2000 PSI (10/04/02 WAlVER)"** Minimum ID = 2.313" 8342' 27/8" REDUCED NIPPLE 5754 7438 8136 1 6 18 24 4-1/2" TBG, 12.6#, L-80, 3- 3-3/8" 4 3-3/8" 4 3-1/8" 4 3-1/8" 4 3-1/8" 4 ÆRFORA TION SUMMARY REF LOG: SWS BHCS ON 10/30/80 ANGLE AT TOP ÆRF: 21 @ 8897' Note: Refer to Production DB INTERVAL 8897-8924 9012-9020 9027-9107 9108-9132 9137-9144 9149-9182 FISH - (2) 3-1/2" SPINNER BLADES ElL (10/17102) COMMENTS PRUDHOE SA Y UNIT WELL: Ä-12 ÆRMIT No: 1801170 API No: 50-029-20515-00 SEe 35, Sf> BP WSUPAT» OETAlLS Pló!ln#$ A--1~A SOO2'f¡I.2.0S1501 PahuttW.i!t»dh: A.12 Tho 0010 MD: $11:00,00 Rig: Ref. DaJuMI 13 : n 1011411-&80 00:00 17_ V.$~ o."k~!~ ';~= ~:~Ð ?lAD \ 04VV, \ '40 .\ 830cr ' , ' - \\ ,WN, N:: W" :, J: ¡'8500 _' . ' , C8550,' ',' ¡¡ u :e cþ NOV :> cþ UV, i! , FQUV, ^' : " , , , : '~v, . 1200 1100 ",.. , .. , ~c : .~ -- MM '^ LEGEND Azimuths to True North PJarr Plan #6 (A-12/PJan#6 A-12A) Magnetic North: 25220 Created By: OJgitai 8usiness Clien.t UserOate 5/5/2004 Magnetic Field Strength: 575850 T Dip Angle: 80.830 Date: 5/5/2004 Model: bggm2003 .... " J : , ..,~:t .~ . ... )~~- ' , \ ;U>t . ;~ . . , \ ' :Ql --~~- .. uc :: , 'AM ..900 ..800 eno ·600 .500 West(-)/East(+} [100ft/in) 1)0 2')0 300 400 500 \ ..c~ , ,',', "~\,< , "'~ _r~~~,~ ~I [~.~ ,-',- 850 900 950 1000105011001150120012501300 1350 1400 1450 1500 1550 1600 1650 1700 1750 1800 185019001950200020502100215022002250230023502400 2450 2500 2550 2600 2650 2700 2750 Vertical Section at 321.00· [50ft/in] .., ' -"-' H' ~~~. :~ = . ·300 ·200 ·100 , ¡8~: ","J,;~:!:;. ;>f=.~~ ~~'_ r: ''<~iD]J ~"..l!"'J " " , ' , , , , , . ObP . BP-GDB Baker Hughes INTEQ Planning Report . B.. BAKaa IIUGIIH """.._-".."",,~,,",".,,,.,,"" IN'fEQ Compjlny: BP ArMco Fietd: Prudhoe Bay Site: PB A Pad Well: A-12 Wellpath: Plan#6 A-12A [ ;Ield: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) l Sys Datum: Mean Sea Level Date: 5/5/2004 Time: 16:36:10 Page: CO-Grdinate(NE) Reference: Well: A-12, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (O.00N.0.00E,321.00Azi) Survey CjllcnlatioD Method: Minimum Curvature Db: t Oracle Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 C"" Site: PB A Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: 5946131.57 ft From: Map Eastlng: 653509.42 ft Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Latitude: 70 15 Longitude: 148 45 North Reference: Grid Convergence: 35.209 N 32.775 W True 1.17 deg l _J J 1~"Well: A-12 A-12 Well Position: Slot Name: 12 +N/-S 3181.13 ft Northing: +E/-W 1003.29 ft Easting: L Position Uncertainty: 0.00 ft r Wellpath: Plan#6 A-12A 500292051501 l Current Datum 13: 1210/14/198000:00 ~agnetic Data/ 5/5/2004 Field Strength: 57585 nT ~~_r~~al Sect.ion: Depth {¡rom (TV D) 30.40 5949332.25 ft 654447.58 ft Latitude: Longitude: 70 16 6.495 N 148 45 3.571 W ~- Height 77.40 ft Drilled From: Tie-Gn Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 A-12 8800.00 ft Mean Sea Level 25.22 deg 80.83 deg Direction deg 321.00 -- +N/-S ft 0.00 ~~ Targets ¡--- Map Map <.-. Latitude --> <- Longitude --> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft - A-12A Fault 1 0.00 1588.78 -1003.27 5950900.00 653412.00 70 1622.120N 148 45 32.780 W -Polygon 1 0.00 1588.78 -1003.27 5950900.00 653412.00 70 1622.120N 148 45 32.780 W -Polygon 2 0.00 1479.75 -77.25 5950810.00 654340.00 70 16 21.048 N 148 45 5.820 W I A-12A Anomaly 1 0.00 1845.74 -1095.03 5951155.00 653315.00 70 16 24.647 N 148 45 35.453 W -Polygon 1 0.00 1845.74 -1095.03 5951155.00 653315.00 70 16 24.647 N 148 45 35.453 W -Polygon 2 0.00 2396.46 -878.67 5951710.00 653520.00 70 16 30.063 N 148 4529.155 W A-12A Polygon6.2 0.00 1419.92 -573.62 5950740.00 653845.00 70 16 20.459 N 148 45 20.271 W -Polygon 1 0.00 1419.92 -573.62 5950740.00 653845.00 70 16 20.459 N 148 45 20.271 W -Polygon 2 0.00 1824.38 -785.38 5951140.00 653625.00 70 16 24.437 N 148 45 26.437 W -Polygon 3 0.00 1980.51 -1082.26 5951290.00 653325.00 70 16 25.972 N 148 45 35.081 W -Polygon 4 0.00 2018.21 -1456.59 5951320.00 652950.00 70 16 26.342 N 148 45 45.981 W -Polygon 5 0.00 2258.17 -1451.67 5951560.00 652950.00 70 16 28.703 N 148 4545.839 W -Polygon 6 0.00 2216.35 -632.29 5951535.00 653770.00 70 16 28.292 N 148 45 21.981 W -Polygon 7 0.00 1959.44 -542.54 5951280.00 653865.00 70 16 25.766 N 148 45 19.367 W ·Polygon 8 0.00 1385.20 -344.26 5950710.00 654075.00 70 1620.118 N 148 45 13.593 W A-12A T6.3 8660.00 2105.06 -814.63 5951420.00 653590.00 70 16 27.198 N 148 45 27.290 W A-12A T6.4 8750.00 2156.41 -1123.66 5951465.00 653280.00 70 16 27.702 N 148 45 36.288 W A-12A T6.1 8800.00 1308.81 -520.88 5950630.00 653900.00 70 16 19.367 N 148 45 18.735 W A-12A T6.2 8800.00 1588.77 -515.13 5950910.00 653900.00 70 16 22.120 N 148 45 18.568 W I A-12A T6.5 8850.00 2062.50 -1372.66 5951366.00 653033.00 70 16 26.778 N 148 45 43.537 W BP-GDB Baker Hughes INTEQ Planning Report MD TVD ft ft ·~·-~·_··_·~_·~_·~~_~__·___~_c_"_.__~~_~~_ 8800.00 8532.46 TIP 8896.00 8621.25 KOP 8916.00 8639.71 3 9234.90 8803.61 4 9394.90 8802.25 5 9659.90 8800.31 6 9757.56 8787.30 7 9872.56 8757.40 8 I 10187.56 8672.88 9 110287.56 8660.34 10 10387.56 8668.65 11 10662.56 8749.92 12 10762.56 8789.42 13 l1_~~~~~~_ 8850.23 TO r Plan: Plan #6 l Identical to Lamar's Plan #6 Principal: Yes ---~._~- Obp . ~ - - Company: BP Amoco Field: Prudhoe Bay Site: PB A Pad Well: A-12 Wellpath: Plan#6 A·12A -- ..-------. Annotation - ----... .__.~- Plan Section Information -- MD Incl Azim TVD ft deg deg ft 8800.00 22.98 352.21 8532.46 8896.00 21.73 351.34 8621.25 8916.00 23.53 351.34 8639.71 9234.90 90.50 351.34 8803.61 9394.90 90.46 15.34 8802.25 9659.90 90.35 335.59 8800.31 9757.56 105.00 335.59 8787.30 9872.56 104.90 353.45 8757.40 10187.56 104.40 304.51 8672.87 10287.56 90.03 300.17 8660.34 10387.56 80.45 288.57 8668.65 10662.56 66.45 247.89 8749.92 10762.56 67.30 264.18 8789.42 10925.00 69.42 238.04 8850.23 _._-~--'-~-~-~-'-~-~-~~- Survey I-~ Incl Azim SSTVD I MD f ft deg deg . ft -----'---~~----------'-.- 8800.00 22.98 352.21 8532.46 8825.00 22.65 351.99 8555.51 8850.00 22.33 351.77 8578.61 8875.00 22.00 351.54 8601.76 8896.00 21.73 351.34 8621.25 8900.00 22.09 351.34 8624.96 8916.00 23.53 351.34 8639.71 8925.00 25.42 351.34 8647.90 8938.56 28.27 351.34 8660.00 8950.00 30.67 351.34 8669.95 8975.00 35.92 351.34 8690.84 9000.00 41.17 351.34 8710.39 9025.00 46.42 351.34 8728.43 9050.00 51.67 351.34 8744.81 9058.54 53.46 351.34 8750.00 9075.00 56.92 351.34 8759.40 9100.00 62.17 351.34 8772.06 9125.00 67.42 351.34 8782.71 9150.00 72.67 351.34 8791.23 - . Bií. BAKIIa HUGIll. INrEQ Date: 5/5/2004 Time: 16:36:10 Page: 2 j Co-ordinate(N(;) Reference: Well: A-12, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (O.00N,O.00E,321.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle . "-_. -~ ---~~~~~-~---~ -----~- Date Composed: Version: Tied-to: 5/5/2004 ~ 4 From: Definitive Path ---~ +N/-S +E/-W DLS Build Turn TFO Target ft ft deg/10OO deg/10OO deg/10OO deg 886.62 -435.33 0.00 0.00 0.00 0.00 922.76 -440.54 1.35 -1.30 -0.91 194.43 930.37 -441.70 9.00 9.00 0.00 0.00 1180.02 -479.72 21.00 21.00 0.00 0.00 1338.58 -470.47 15.00 -0.03 15.00 90.00 1597.48 -491.00 15.00 -0.04 -15.00 270.00 1685.37 -530.89 15.00 15.00 0.00 0.00 1791.95 -560.41 15.00 -0.08 15.53 88.00 2044.04 -712.18 15.00 -0.16 -15.54 276.00 2096.91 -795.79 15.00 -14.37 -4.34 197.00 2137.98 -886.27 15.00 -9.58 -11.60 230.00 2133.54 -1142.76 15.00 -5.09 -14.79 245.00 2111.49 -1231.63 15.00 0.85 16.29 90.00 2062.91 -1372.81 15.00 1.30 -16.10 270.00 -- J N/S EIW MapN MapE VS DLS TFO Tooll ft ft ft ft ft deg/100ft deg 886.62 -435.33 5950209.69 653994.19 963.00 0.00 0.00 TIP 896.23 -436.66 5950219.27 653992.66 971.30 1.35 194.43 MWD 905.69 -438.01 5950228.70 653991.12 979.50 1.35 194.63 MWD 915.03 -439.38 5950238.00 653989.56 987.62 1.35 194.83 MWD 922.76 -440.54 5950245.71 653988.24 994.36 1.35 195.05 KOP 924.24 -440.77 5950247.18 653987.98 995.65 9.00 0.00 MWD 930.37 -441.70 5950253.29 653986.92 1001.00 9.00 0.00 3 934.05 -442.26 5950256.97 653986.28 1004.22 21.00 0.00 MWD 940.11 -443.18 5950263.00 653985.24 1009.51 21.00 360.00 A-12A T! 945.67 -444.03 5950268.54 653984.28 1014.36 21.00 0.00 MWD 959.23 -446.10 5950282.06 653981.93 1026.20 21.00 0.00 MWD 974.63 -448.44 5950297.40 653979.27 1039.64 21.00 0.00 MWD 991.73 -451.05 5950314.44 653976.32 1054.57 21.00 0.00 MWD 1010.39 -453.89 5950333.04 653973.10 1070.86 21.00 0.00 MWD 1017.09 -454.91 5950339.72 653971.94 1076.71 21.00 360.00 A-12A T€ 1 030.45 -456.94 5950353.03 653969.63 1088.37 21.00 0.00 MWD 1051.75 -460.19 5950374.26 653965.95 1106.96 21.00 0.00 MWD 1074.10 -463.59 5950396.54 653962.09 1126.48 21.00 0.00 MWD 1097.32 -467.13 5950419.68 653958.08 1146.75 21.00 0.00 MWD ObP . BP-GDB Baker Hughes INTEQ Planning Report . .ii. BAIda IIUGIIIS INfEQ II· Company: BP Amoco Date: 5/5/2004 TÍlne: 16:36:10 Page: 3 Field: Prudhoe Bay CO-{lrdinate(NE) Reference: Well: A·12, True North Site: PB A Pad Vertical (TVD) Reference: System: Mean Sea Level Well: A-12 Section (VS) Reference: Well (0.00N,O.00E,321.00Azi) Wellpath: Plan#6 A-12A Survey Calculation Method: Minimum Curvature Db: Oracle I - Survey MD Incl Azim SSTVD N/S EIW MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/1ooft deg - .- 9175.00 77.92 351.34 8797.58 1121.22 -470.77 5950443.49 653953.95 1167.62 21.00 0.00 MWD 9200.00 83.17 351.34 8801.68 1145.59 -474.48 5950467.78 653949.74 1188.89 21.00 0.00 MWD 9225.00 88.42 351.34 8803.52 1170.23 -478.23 5950492.34 653945.48 1210.40 21.00 0.00 MWD I 9234.90 90.50 351.34 8803.61 1180.02 -479.72 5950502.10 653943.79 1218.95 21.00 0.00 4 I 9250.00 90.50 353.60 8803.48 1194.98 -481.70 5950517.01 653941.50 1231.82 15.00 90.00 MWD 9275.00 90.50 357.35 8803.26 1219.90 -483.67 5950541.88 653939.02 1252.43 15.00 90.02 MWD 9300.00 90.49 1.10 8803.04 1244.89 -484.01 5950566.86 653938.17 1272.06 15.00 90.05 MWD 9325.00 90.49 4.85 8802.83 1269.85 -482.71 5950591.84 653938.96 1290.64 15.00 90.08 MWD 9350.00 90.48 8.60 8802.62 1294.68 -479.78 5950616.72 653941.38 1308.09 15.00 90.12 MWD 9375.00 90.47 12.36 8802.41 1319.25 -475.23 5950641.38 653945.42 1324.33 15.00 90.15 MWD 9394.90 90.46 15.34 8802.25 1338.58 -470.47 5950660.80 653949.79 1336.35 15.00 90.18 5 9400.00 90.46 14.58 8802.21 1343.50 -469.15 5950665.75 653951.00 1339.34 15.00 270.00 MWD 9425.00 90.46 10.83 8802.01 1367.88 -463.66 5950690.23 653955.99 1354.84 15.00 269.99 MWD 9450.00 90.45 7.08 8801.82 1392.57 -459.77 5950715.00 653959.37 1371.58 15.00 269.96 MWD 9475.00 90.45 3.33 8801.62 1417.47 -457.50 5950739.93 653961.13 1389.49 15.00 269.93 MWD 9500.00 90.44 359.58 8801.43 1442.45 -456.87 5950764.92 653961.25 1408.51 15.00 269.90 MWD 9525.00 90.43 355.83 8801.24 1467.43 -457.87 5950789.87 653959.73 1428.55 15.00 269.88 MWD 9550.00 90.42 352.08 8801.05 1492.28 -460.51 5950814.66 653956.59 1449.53 15.00 269.85 MWD I 9575.00 90.41 348.33 8800.87 1516.91 -464.76 5950839.20 653951.83 1471.35 15.00 269.82 MWD I 9600.00 90.39 344.58 8800.70 1541.21 -470.62 5950863.37 653945.48 1493.92 15.00 269.79 MWD 9625.00 90.38 340.83 8800.53 1565.08 -478.05 5950887.08 653937.56 1517.14 15.00 269.77 MWD 9650.00 90.36 337.08 8800.37 1588.40 -487.03 5950910.21 653928.11 1540.92 15.00 269.74 MWD 9659.90 90.35 335.59 8800.31 1597.48 -491.00 5950919.20 653923.95 1550.47 15.00 269.72 6 9675.00 92.62 335.59 8799.92 1611.22 -497.24 5950932.81 653917.43 1565.07 15.00 0.00 MWD 9700.00 96.37 335.59 8797.96 1633.91 -507.54 5950955.28 653906.67 1589.19 15.00 0.00 MWD 9725.00 100.12 335.59 8794.38 1656.43 -517.76 5950977.59 653895.99 1613.13 15.00 0.00 MWD 9750.00 103.87 335.59 8789.18 1678.70 -527.86 5950999.64 653885.43 1636.79 15.00 0.00 MWD 9757.56 105.00 335.59 8787.30 1685.37 -530.89 5951006.25 653882.26 1643.88 15.00 0.00 7 9775.00 105.08 338.30 8782.77 1700.86 -537.49 5951021.60 653875.35 1660.07 15.00 88.00 MWD 9800.00 105.13 342.18 8776.26 1723.57 -545.64 5951044.14 653866.73 1682.85 15.00 88.70 MWD 9825.00 105.11 346.07 8769.73 1746.78 -552.25 5951067.21 653859.66 1705.04 15.00 89.71 MWD 9850.00 105.03 349.95 8763.23 1770.39 -557.26 5951090.70 653854.16 1726.55 15.00 90.73 MWD 9872.56 104.90 353.45 8757.40 1791.95 -560.41 5951112.20 653850.57 1745.29 15.00 91.74 8 9875.00 104.94 353.07 8756.78 1794.29 -560.68 5951114.53 653850.25 1747.28 15.00 276.00 MWD I 9900.00 105.29 349.21 8750.25 1818.13 -564.40 5951138.29 653846.04 1768.14 15.00 275.90 MWD 9925.00 105.58 345.33 8743.60 1841.63 -569.71 5951161.67 653840.25 1789.75 15.00 274.89 MWD 9950.00 105.80 341 .44 8736.83 1864.69 -576.59 5951184.59 653832.90 1812.00 15.00 273.86 MWD 9975.00 105.95 337.54 8729.99 1887.21 -585.01 5951206.92 653824.02 1834.80 15.00 272.81 MWD 10000.00 106.03 333.64 8723.11 1909.09 -594.94 5951228.59 653813.64 1858.05 15.00 271.74 MWD 10025.00 106.03 329.74 8716.20 1930.24 -606.34 5951249.50 653801.82 1881.66 15.00 270.67 MWD 10050.00 105.97 325.84 8709.31 1950.57 -619.14 5951269.56 653788.60 1905.51 15.00 269.59 MWD 10075.00 105.84 321.94 8702.45 1969.99 -633.31 5951288.69 653774.04 1929.52 15.00 268.52 MWD 10100.00 105.64 318.05 8695.67 1988.42 -648.77 5951306.79 653758.20 1953.57 15.00 267.45 MWD 10125.00 105.37 314.17 8688.98 2005.77 -665.47 5951323.80 653741.15 1977.57 15.00 266.39 MWD 10150.00 105.03 310.30 8682.43 2021.99 -683.33 5951339.64 653722.96 2001.41 15.00 265.35 MWD 10175.00 104.63 306.44 8676.02 2036.98 -702.27 5951354.25 653703.72 2024.99 15.00 264.34 MWD 10187.56 104.40 304.51 8672.87 2044.04 -712.18 5951361.10 653693.67 2036.71 15.00 263.35 9 10200.00 102.62 303.95 8669.97 2050.84 -722.17 5951367.70 653683.54 2048.28 15.00 197.00 MWD 10225.00 99.03 302.85 8665.28 2064.36 -742.67 5951380.79 653662.77 2071.68 15.00 196.87 MWD l'0250·oa 95.43 301.77 8662.13 2077.61 -763.63 5951393.61 653641.55 2095.17 15.00 196.66 MWD 10275.00 91.84 300.71 8660.54 2090.55 -784.96 5951406.10 653619.96 2118.65 15.00 196.53 MWD 10287.56 90.03 300.17 8660.34 2096.91 -795.79 5951412.24 653609.00 2130.41 15.00 196.46 10 ObP . BP-GDB . ... BAKU: ..... Baker Hughes INTEQ Planning Report INIEQ r C~mpany: BP Amoco Date:. 5/5/2004 Time: 16:36:10 Page: 4 I Field: Prudhoe Bay Co-ordinate{NE) ReferenCe: Well: A-12, True North Site: PB A Pad Vertical (TVD) Reference: System: Mean Sea Level Well: A,12 Section (VS) Reference: Well (0.00N,O.00E,321.00Azi) l Wellpath: Plan#6 A,12A Survey Calculation Method: Minimum Curvature Db: Oracle Survey ~~D Incl Azim SSTVI> N/S E/W MapN MapE VS DLS TFO TO~ 10:ÕO.00 deg deg ft ft ft ft ft ft deg/10OO deg 88.83 298.74 8660.46 2103.03 ,806.61 5951418.13 653598.05 2141.98 15.00 230.00 MWD I 10325.00 86.42 295.86 8661.50 2114.48 ,828.81 5951429.13 653575.63 2164.85 15.00 230.01 MWD 10350.00 84.03 292.97 8663.58 2124.78 -851.49 5951438.96 653552.75 2187.12 15.00 230.13 MWD 10375.00 81.64 290.05 8666.70 2133.88 ,874.56 5951447.58 653529.49 2208.71 15.00 230.37 MWD I I I 10387.56 80.45 288.57 8668.65 2137.98 -886.27 5951451.44 653517.70 2219.27 15.00 230.74 11 10400.00 79.67 286.85 8670.80 2141.71 ,897.94 5951454.93 653505.96 2229.51 15.00 245.00 MWD 10425.00 78.12 283.37 8675.61 2148.10 ,921.62 5951460.84 653482.16 2249.38 15.00 245.30 MWD 10450.00 76.62 279.85 8681.08 2153.02 -945.51 5951465.26 653458.17 2268.23 15.00 245.97 MWD 10475.00 75.16 276.29 8687.18 2156.42 -969.51 5951468.17 653434.11 2285.99 15.00 246.74 MWD 10500.00 73.76 272.68 8693.88 2158.31 ,993.51 5951469.56 653410.07 2302.56 15.00 247.61 MWD 10525.00 72.42 269.02 8701.15 2158.66 ,1017.43 5951469.43 653386.16 2317.88 15.00 248.57 MWD 10550.00 71.15 265.30 8708.96 2157.49 -1041.14 5951467.77 653362.48 2331.89 15.00 249.64 MWD 10575.00 69.96 261.53 8717.29 2154.79 ,1064.55 5951464.59 653339.12 2344.53 15.00 250.80 MWD 10600.00 68.85 257.71 8726.09 2150.58 -1087.57 5951459.91 653316.20 2355.74 15.00 252.06 MWD 10625.00 67.82 253.83 8735.32 2144.87 ,1110.08 5951453.74 653293.81 2365.47 15.00 253.40 MWD 10650.00 66.89 249.89 8744.95 2137.69 -1132.00 5951446.11 653272.04 2373.69 15.00 254.84 MWD 10662.56 66.45 247.89 8749.92 2133.54 -1142.76 5951441.74 653261.37 2377.23 15.00 256.35 12 10675.00 66.47 249.93 8754.89 2129.43 -1153.40 5951437.42 653250.82 2380.74 15.00 90.00 MWD 10700.00 66.57 254.01 8764.86 2122.34 -1175.20 5951429.88 653229.17 2388.94 15.00 89.19 MWD 10725.00 66.79 258.09 8774.76 2116.81 -1197.47 5951423.89 653207.02 2398.66 15.00 87.56 MWD 10750.00 67.10 262.15 8784.55 2112.86 -1220.13 5951419.48 653184.45 2409.86 15.00 85.94 MWD 10762.56 67.30 264.18 8789.42 2111.49 -1231.63 5951417.87 653172.98 2416.02 15.00 84.35 13 10775.00 67.31 262.16 8794.22 2110.12 ,1243.02 5951416.27 653161.62 2422.13 15.00 270.00 MWD I 10800.00 67.42 258.10 8803.84 2106.17 ,1265.75 5951411.85 653138.98 2433.36 15.00 270.78 MWD 10825.00 67.62 254.05 8813.40 2100.61 -1288.16 5951405.84 653116.69 2443.15 15.00 272.34 MWO J 10850.00 67.93 250.01 8822.86 2093.47 ,1310.17 5951398.25 653094.83 2451.45 15.00 273.89 MWD 10875.00 68.33 245.99 8832.18 2084.78 ,1331.68 5951389.12 653073.51 2458.23 15.00 275.42 MWD 10900.00 68.83 242.00 8841.31 2074.58 ,1352.59 5951378.49 653052.82 2463.46 15.00 276.92 MWD 10924.36 69.40 238.14 8850.00 2063.23 -1372.30 5951366.74 653033.34 2467.05 15.00 278.38 A,12A T 10925.00 69.42 238.04 8850.23 2062.91 -1372.81 5951366.41 653032.83 2467.12 15.00 279.75 TO J . BOP-Tree . KB Elevation Well Rig Floor ........................................................................................ ........................................................................................ .................................'...................................................... ............................,........................................................... 111¡1¡·¡I;;;;;;;;;;;i~¡¡¡I;;;¡¡;¡:~;,¡i;:;;;;;:;;;111111111 It:.~~1:8~~::g~¡::~~;~~:::·!8·f·t;~8 .............., / .......J;~;~;~;~;~;~;:;~~:~~;~~!~!;!;:~t.....:----1:t:Mj~MQM::~W:R*~:.::: .::.., ·:r:tijlil&¡tJM6WêMi~fw.M~@8¡¡~·ô.H¡$Mr:} .. þ~~$.QÞ91M¡ .:::.:.:.:.:.:K:::.:.:.:.: Blin~~~ears :::.:::::::::::::.:::...:.::., IV4rrQifm;æVjji.$. i' // // .... t]f1i!W~gg:¡@j:~a~M~gm· !Jit$.n~ºº~fp.#.@R*@~Ff .................................................. ................... . ......... ..... ~ Swab Valve Tree Size SSV I Master Valve Base Flange Page 1 . . TERRIE l HUBBLE BP EXPLORATION AK INC PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 89-6/1252 104 "Mastercard Check" DATE Anchorage, AK 99501 $ ,._./. ·'''r·~ µ,. ð (l,.P>j : -~¡ MEMO ' i. " /~~ r: I: ¡. 25 2000bOI:Qq ¡'~"·b 2 2 7"· ¡. 55b"- 0 ¡'O~ . . TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /ð q ,4- /ZA PTD# 2 C) ~ - 0 7 '1 Exploration Stratigraphic x '" Development Service CHECK WßA T ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI Tbe permit is for a new weUbore segment of LATERAL existing well , Permit No, API No. . (If API number ProductionshouJd continue to be reponed as Jast two (2) digits a function' of tbe original API number. stated are between 60-69) above. Pn,OT HOLE ]n accordance with 20 MC 25.005(f), aU (PH) records, data and Jogs acquired for the piJot boJe must be dearly differentiated in both name (name OD permit plus PH) aDd API Dum ber (50 - 70/80) from records, data and Jogs acquired for weU (name on permit). SPACING Tbe permit is approved subject ·to fuD EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing e:J ception. (Companv Name) assumes tbe liability of any protest to tbe spacing .exception tbat may occur. DRY DITCH An dry ditcb sample sets su bmitted to tbe SAMPLE Commission must be in no greater -tban 30' sampJe intervals from beJow tbe permafrost or from where samples are first caught and ] 0' sample intervals tbrough target zones. . . D D Well bore seg Annular Disposal PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT A-12A _Program DEV ALASKA) INC Initial ClassfType _DEV /.1~GeoArea 890 Unit 1165~ On/Off Shore 011 Administration Pßrmit fee attache.d - - - - - - - - - - - - - - - YßS 2 .Leasß .numberappropriatß. . YßS. 3 .U.nique weltllamß.a!1d oumb.er . . . . . . . . . . . . . . . . . . . . . . ... ..... .YßS.. - - - - - - - - - - - - - - - - - - - - 4 Well JQcatßd in.a d.efine~l.ppol. . . .. - - - - - .YßS. 5 WelUQcatßd pr.oper .distance from driJIing unitboundal)'. . . - - - - - Yßs. 6 Well JQcat~d pr.oper .distance. from Qtber welJs. . . . Yes. - - - - - -- 7 .S.utficient acreaQ.e.ayailable in.driUiOQ.unjt - - - -- Yes. 8 Jf.d~viated, is. weJlbQre plat.incJu.ded . Y~s 9 .Operator only affected party. . . . . . - - - - Y~s 10 .Operator bas.appropriate. bond inJQrce . . . . . . . . . . . . . . . . . __.__.__Yes - - - - - - - - - - - - - -. - - 11 P~rmit can be issued witbQut co.nservaJion order - - - - - .. YßS Appr Date 12 Pßrmit cao be issued witbout administrativ.e.apprpvaJ . . - - - - - - ... Yßs - - - - RPC 5/7/2004 13 Can permit be approved before 15-ctay wait Yes 14 Well JQcatßd within area and strata authorized by.lojectiolJ Ordßr # (put 10# in. c.ommßots) (For. NA 15 .AJI welJs.withinJl4)·uile.area.of reyieW jdßotified (F.or servjcßwell only). . . . . . . . . . . . . .NA - - - - - - - - - - - - - - - - - - -- 16 Pre-produced i!1jector; .duratiQn.of pre-pro.duGtiplJ IßSS than 3 months. (For service well QnJy) NA - - - - -- - - - - 17 .ACMP finding of CQn$i$teocy. has been is.sued. for tbis proiect - - - - NA - - - - - - - -- Engineering 18 .Coodu.ctor string.prQvided . . . - - - - - - - - - - -- .NA Sidetrack. - - - - - 19 .S.ur:fac~casing.PJQtec.ts alLknown USDWs . NA 20 .CMT vol adequate. to circ.ulate on .cond.uctpr & SUJ(csg . NA 21 .CMT vol adeQuateJo tie-i.nJQngstring to.sur:f csg. . NA - - - -- - - - ~ - - 22 .CMT will coyer .all \<.lJowJ\productiye bQrizQn.s. . .YßS 23 .C.asiog desig!1s adequaJe f.or C,.T" B .&. permafr.ost Yes 24 .Adequate.tankage OJ re.serve pit - - -- YßS CTDU. 25 Jf.aJe-drilt hasa. to.-40;3 fQr abandonme.nt beßO apprQved . YßS * - - - - - - - - - - - - - 26 .A.dequatewellbore separatjo.n.proppsed. . . . . . . . . . . . . . . . . . . .YßS - - - - - - - - - - - - - - - - - - - - 27 If.diverter required, dQes jt meet. reguJatiolJs. . . NA Sidetrack.. . . . Appr Date 28 .DJiUiog fluid program sc.hematic.& ectuip Jistadequatß. . . . Yßs MaxMW.8~7.ppg. . . . . . . WGA 5/10/2004 29 .BOPEs,d.o.they meetreguJatiolJ . . . - - - - - Yes - - - -- - - - - - 30 .sOPEpress raJiog appropriate; .test to .(put psig in .commelJts). . . Yßs Test t.o .3500. psi.MSF' 23.70 psi.. 31 .Choke.manifold cQmpJies w/APtRF'-53. (May 84). . . . . . . YßS 32 WQrk will pccur withput .operation .sbutdown. . - - - - .YßS 33 .Is presence. Qf H2S gas. probable. - - - - - - Yßs 2QO.ppm, 34 MechanicaLcplJditloo.of wells within ,ð.OR yerified (Fpcs.ervice w~1J only) NA Geology 35 Pßrmit c.ao be issued wlo hydrogen s.ulfide meaSures No. 36 D.atapreseoted on pote.ntial pverpressure .zOlJes. . .NA Appr Date 37 .Sßismicanalysjs. Qf shaJlow gas.z.ooes NA RPC 5/7/2004 38 .Sßabed .colJditipo survey.(if off-shore) NA 39 . CQntact narnelphoneJor.weeldy pro )rts [I .NA - Geologic Date: Engineering Date Commissioner: Commissioner: DTJ ~J¡Ó/ 1-
