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Home My WebLink About205-004 • • Post Office Box 244027 t� Anchorage,AK 99524-4027 Hilcorp Alaska,LLC JUL 3 0 2P) 3800 Centerpoint Drive Suite 100 GCCAnchorage,AK 99503 Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 Commissioner Cathy Foerster Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 a ds_ 00 It Anchorage, AK 99501 33V l _ C' Re: Duck Island Unit Well Renaming Request Dear Commissioner Foerster, SCANNED`' Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "/" followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/L21" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD # 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/T34" (PTD# 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp • Orig . New API_WellNo PermitNumber WellName WellNumber WellNumber 50029218010000 1880370 DUCK IS UNIT MPI 1-01/119 1-01 50029226010000 1951500 DUCK IS UNIT MPI 1-03/P16 1-03 50029216050000 1861060 DUCK IS UNIT MPI 1-05/020 1-05 50029217430000 1870810 DUCK IS UNIT MPI 1-09/118 1-09 50029217430100 1970290 DUCK IS UNIT MPI 1-09A/L21 1-09A 50029221070000 1901570 DUCK IS UNIT MPI 1-11/SN4 1-11 50029223610000 1930560 DUCK IS UNIT MPI 1-15/P25 1-15 50029221000000 1901500 DUCK IS UNIT MPI 1-17/SN2 1-17 50029221000100 1961990 DUCK IS UNIT MPI 1-17A/117 1-17A 50029225690000 1950930 DUCK IS UNIT MPI 1-19/118 1-19 50029220050000 1900020 DUCK IS UNIT MPI 1-21/K25 1-21 50029225100000 1941280 DUCK IS UNIT MPI 1-23/015 1-23 50029217220000 1870420 DUCK IS UNIT MPI 1-25/N22 1-25 50029217220100 1970750 DUCK IS UNIT MPI 1-25A/K22 1-25A 50029216930000 1870090 DUCK IS UNIT MPI 1-27/P20 1-27 50029216690000 1861810 DUCK IS UNIT MPI 1-29/M25 1-29 50029225620000 1950720 DUCK IS UNIT MPI 1-31/M21 1-31 50029225770000 1951070 DUCK IS UNIT MPI 1-33/M23 1-33 50029225770100 1980870 DUCK IS UNIT MPI 1-33A/L24 1-33A 50029225770200 1982550 DUCK IS UNIT MPI 1-33B/L24 1-33B 0029225770300 2050040 DUCK IS UNIT MPI 1-33C/M24XX 1-33CXX 50029216720000 1861840 DUCK IS UNIT MPI 1-35/025 1-35 50029217480000 1870900 DUCK IS UNIT MPI 1-37/P24 1-37 50029218270000 1880630 DUCK IS UNIT MPI 1-39/P17 1-39 50029218270100 2061870 DUCK IS UNIT MPI 1-39A/N-16 1-39A 50029217130000 1870320 DUCK IS UNIT MPI 1-41/023 1-41 50029218640000 1881050 DUCK IS UNIT MPI 1-43/P26 1-43 50029219910000 1891240 DUCK IS UNIT MPI 1-45/026 1-45 50029216250000 1861310 DUCK IS UNIT MPI 1-47/021 1-47 50029216250100 1972030 DUCK IS UNIT MPI 1-47A/M20 1-47A 50029218410000 1880780 DUCK IS UNIT MPI 1-49/P21 1-49 50029223040000 1921190 DUCK IS UNIT MPI 1-51/V20 1-51 50029225010000 1941120 DUCK IS UNIT MPI 1-53/Q20 1-53 50029217880000 1880210 DUCK IS UNIT MPI 1-55/R25 1-55 50029218730000 1881140 DUCK IS UNIT MPI 1-57/R23 1-57 50029226440000 1960220 DUCK IS UNIT MPI 1-59/024 1-59 50029225200000 1941420 DUCK IS UNIT MPI 1-61/Q20 1-61 50029219050000 1890060 DUCK IS UNIT MPI 1-63/T22 1-63 50029226270000 1951880 DUCK IS UNIT MPI 1-65/N25 1-65 50029226270100 2032120 DUCK IS UNIT MPI 1-65A/N27 1-65A 50029219850000 1891140 DUCK IS UNIT MPI 1-67/T20 1-67 50029220200000 1900290 DUCK IS UNIT MPI 1-69/V19 1-69 50029215680000 1860630 DUCK IS UNIT MPI 2-02/P18 2-02 50029215850000 1860820 DUCK IS UNIT MPI 2-04/M19 2-04 50029216990000 1870180 DUCK IS UNIT MPI 2-06/J22 2-06 50029217710000 1880040 DUCK IS UNIT MPI 2-08/K16 2-08 50029223020000 1921170 DUCK IS UNIT MPI 2-12/016 2-12 50029216390000 1861490 DUCK IS UNIT MPI 2-14/016 2-14 50029218850000 1881340 DUCK IS UNIT MPI 2-16/M16 2-16 50029220320000 1900430 DUCK IS UNIT MPI 2-18/L16 2-18 50029220480000 1900600 DUCK IS UNIT MPI 2-20/L15 2-20 50029219310000 1890340 DUCK IS UNIT MPI 2-22/L14 2-22 · . 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. S)¡)S - Q 0 ~ Well History File Identifier Organizing (done) D Two-sided 1111111111111111111 D Rescan Needed 1111111111111111111 RESCAN DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Color Items: D Greyscale Items: D Diskettes, No. D Other, Noffype: D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: NOTES: Date 1/13/07 # I o Other:: BY: ~ /5/ YYVP Date/þaØ7 11111111111111" III Project Proofing BY: ~ /5/ BY: Date: + = TOTAL PAGES (Count does not include cover sheet) /5/ Scanning Preparation Production Scanning 11111111111111" III Stage 1 Page Count from Scanned File: I 5 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES ~ Date: 1/13/07 NO /5/ MP NO BY: Stage 1 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: /5/ 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 11111111111111 "III BY: Maria Date: /5/ Comments about this file: Quality Checked 1111111111111111111 1 0/6/2005 Well History File Cover Page.doc • • x ~.; -_ _. v-- ~"` ..~ MICROFILMED 03/01/2008 DO NOT P LAC E ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFict~lC~rPgs_InsertslMicrofilm Marker.tbc . ~1f~1fŒ mJ~ ~~~~~~ / .U","SKA. ORAND GAS / CONSERVATION COMMISSION / . FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mark O. Johnson CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Endicott 1-33C/M-24 BP Exploration (Alaska) Inc. Permit No: 205-004 Surface Location: 3217' NSL, 2114' WEL, SEC. 36, T12N, R16E, UM Bottomhole Location: 1927' NSL, 4516' EWL, SEC. 31, T12N, R17E, UM Dear Mr. Johnson: 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 notic.e for a representative of the Commission t i ess any required test. Contact the Commission's petroleum field inspector at (907) 659 60 ger). nc el)'í DATED this~day of January, 2005 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. "'""..1, rt 11; " ,". ~ 1a. Type of work o Drill II Redrill 1b. Current Well Class o Exploratory II DevelopÌÌ1årîi Öil. !;::fMr.nflpli!fiì«KiJISSIO ORe-Entry o Stratigraphic Test 0 Service o Development G¡jm . Zone 2. Operator Name: 5. Bond: 181 Blanket 0 Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 2S1oo302630-277 t>:r?t Þ<: ..ENfí1-33C/M-24 3. Address: 6. Proposed Depth: 12. Field / Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 12877 TVD 10075ss Endicott Field / Endicott Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: ADL 312828 3217' NSL, 2114' WEL, SEC. 36, T12N, R16E UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: 1966' NSL, 3983' EWL, SEC. 31, T12N, R17E, UM January 25, 2005 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1927' NSL, 4516' EWL, SEC. 31, T12N, R17E, UM 2560 2015' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool Surface: x- 259089 y- 5982351 Zone- ASP3 (Height above GL): 55.5' feet 709' away at 12062' MD 16. Deviated Wells: Kickoff Depth: 11350 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90 deQrees Downhole: 4832 Surface: 3849 18. CaSIng Program: Specifications Setting Depth .x . uuantity Of ce~ent Size T)p . '. ··Bottom (c.f. or sacks Hole Casino Weioht Grade CouDlina Length MD TVD MD TVD {includino staae data) 4-1/8' x 3-314" 3-3/16" 6.2# L-80 TCII 480' 11170' 9285' 11650' 9709' 140 sx Class 'G' 2.7" x 3" 2-3/8" 4.7# 13Cr STL 1737' 11140' 9316' 12877' 10075' 133 sx Class 'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): I Effective Depth MD (ft): \Effective Depth TVD (ft):\ Junk (measured): 12585 10077 None 12542 10075 None Casing Length Size Cement Volume MD TVD ~ - 90' 30" Driven 130' 130' Sllrf;:¡r.p. 4971' 10-3/4" 795 sx Permafrost "E', 600 sx Class 'G' 5013' 4406' 11685' 7-5/8" 500 sx Class 'G' 11724' 9794' Pr Liner 1438' 2-7/8" 100 sx Class 'G' 11147' - 12585' 9322' - 10077' Perforation Depth MD (ft): 12500' - 12540' IPerfOration Depth TVD (ft): 10072' - 10075' 20. Attachments 181 Filing Fee, $100 181 BOP Sketch 181 Drilling Program 0 Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report 181 Drilling Fluid Program 18120 AAC 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 Mark O. Johnson. 564-5666 Printed Name Mark O. Johnson ____ Title CT Drilling Engineer ;iar ~A ~ L Q. \lr1v Date 11'0 jQS Prepared By Name/Number: SI nature ,/ , Phone 564-5666 Terrie Hubble, 564-4628 // Commission Use Onl} . Permit To Drill I APtþ(umber: Permit Approv~~ I See cover letter for Number:2oS-00 ~ 50-029-22577-03-00 Date: ¡"II 3 ¿?~ other requirements CondO"". of Approvar~ Requ;red DYes -ª,No Mud Log Required D Yes ~~o H rogl n Sulfide Measures ~Yes D No Directional Survey Required ;gYes D No OtherTesY~; 4000 Xi ~¥ IADmov( _1:Jr;1~ APPROVED BY ,/ ~ --- THE COMMISSION Date Form 10-401 R~ed ò6~ ~ UUfJLILAI t Submit In Duplicate . STATE OF ALASKA . ALAS¡""OIL AND GAS CONSERVATION C~MISSION PERMIT TO DRILL 20 AAC 25 005 REcr=r ... .... ",;C\' VED JAN I 0 2005 . . BP Endicott 1-33CIM-24 Sidetrack Summary of Operations: Well Endicott 1-33B/L-24 is scheduled for a through tubing sidetrack with the SLB/Nordic 2 CTD rig. The sidetrack, Endicott 1-33C/M-24, will exit out of the existing 7 5/8" liner from a mechanical whipstock and target Kekituk S2AI reserves. The following describes the planned sidetrack. A schematic diagram of the proposed sidetrack is attached for reference. Pre CTD Summary (Phase 1) 1) Slickline - Drift tubing for whipstock. Dummy gas lift valves. Pressure test IA to 2500 psi. Drift 2 7/8" liner for CIBP. 2) E-line - Set 2 7/8" CIBP at 11430' md. Pressure test wellbore to 1000 psi. P&A is complete. Regardless of pressure test results continue with planned operations. The old wellbore will be isolated by 2 additional cement jobs during the liner completion phases. 3) E-line - Chemical cut 2 7/8" liner above top ofliner cement at 11380' md. 4) Service coil - Grab CPH liner top with releasable spear at 11141' md and pull check liner to confirm free. Set back down. 5) Remove wellhouses and flowlines. Prep pad for Nordic 2 rig. CTD Sidetrack Summary (Phase 2A and 2B) 1) Phase 2A start MIRV Nordic 2. Test BOPs. 2) Kill well. Pull 2 7/8" liner from chemical cut. 3) Vnderream 7 5/8" liner from 11200-11380' md. 4) SL - Log PDS caliper survey of 7 5/8" liner to confirm all cement is gone. 5) Set 4 12" x 75/8" whipstock in 7 5/8" liner at 11350'md. 6) Mill 3.8" OD window at 11350' md. 7) Drill HRZ shale to -11650' to -top of Kekituk. 8) Run and cement 33/16" L-80 protective casing string. End phase 2A. 9) Phase 2B start - Drill 2.7" x r bicenter hole from 11650' to TD at 12871' md with MWD/GR. 10) Log resistivity. 11) Run 23/8" 13Cr solid liner completion and cement. 12) Log memory CNL during liner cleanout run. 13) Perforate. 14) RDMO. Mud Program: · Phase 1: 8.4 ppg seawater · Phase 2A (HRZ): 9-12 ppg NaBr Flo Pro or biozan for milling and drilling HRZ shale. · Phase 2B (Kekituk): 10.0 ppg Flo 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: · Phase 2A - 3-3/16" solid cemented liner completion across HRZ and lap 11170' to 11650' (protective string). The liner cement volume is planned to be -8.2 bbls of 15.8 ppg class G. · Phase 2B - 23/8" solid cemented liner (11140-12877'). The liner cement volume is planned to be -6.8 bbls of 15.8 ppg class G. . . Parent Well Casinas Burst (Dsil CollaDse lDsil 10314" 45.5# L-80 5210 2480 7518" 29.7#, L-80 6890 4790 Sidetrack Casinas 3-3/16" 6.2#, L-80, TCII- Prod LNR 8520 7660 23/8" 4.7#, 13Cr, STL - Prod LNR 11200 11780 Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan. Max. planned hole angle is 90 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. · Endicott l-33C/M-24 will be approx 709'md center to center away from welll-25/N-22 at 12062'md. For the first 200' from sidetrack KOP l-33C/M-24 will be close to previously abandoned 1-33 wellbores. · Endicott l-33C/M-24 will be approx 2015' from the unit boundary. Logging · MWD Gamma Ray log will be run over all of the open hole section. · Resistivity will be run logged after drilling. · CNL memory log after casing. Hazards · Endicott row 1 has illS readings over 100 ppm and is designated as an illS pad. Maximum recorded IDS on the pad was 1200 ppm from 1-196/30/04. The last 1-33 IDS level was 30 ppm in 3/2003. All IDS monitoring equipment will be operational. · Two small fault crossings are anticipated. Lost circulation risk is considered "low", but LCM material will be on location as a contingency. Reservoir Pressure · Res. press. is estimated to be 4832 psi at 9832'ss (9.5 ppg EMW). Max. surface pressure with gas (0.10 psi/ft) to surface is 3849 psi. MOl 1/7/05 Plan: Plan Ø5 (,-33IM-231PtonolS '·33ClM-24) Creoted By: BR1__ Date: ,212812004 Information: = ~~~i7-66'O Cen: 1907) ~5().7375 E·mai : james.ohlinger@inteq.oom AzImuths to True North Magnetic North: 25.34" Magnetic Field Strength: 57662nT Dip Angle: 60.96" Dal8: 12114/2004 Model: bggm2004 LEGEND T '·_(1_23) l - _'_2' - -" ObP . e ... C ~ -1150-" II) .... - _-1200·' + i 01250 . ~ I: o I: Z 01300j ¡ i0135O'j ! .. , -:\ ::a -1400-- :.' o " rn : j -1450- . i -1500-: . i ~ ! -1550 : ¡ :::il::1 -1700 -:j¡'fTiiìf+i ',. ] 5500 5550 BP Amoco _"'MTAIU -.- - -- ........ TIe _... 11..... .... ..:: ~ ~1Nt....... ...... V'"= o:;r: = ::;.~ ...... .... .... .... REFERENCE INFORMATION ~ (NÆ! _: We! CenIre: '.J3IM.23. 7_ Nor1h v_ (7VD _: 11: 09 '2IØ/19M ,0:39 M.OG ...=n~=: ~rÕII~~orø::'~ M.OG ~_:_~ _A_ -- Ii.... 'lIP 11..... ... 11Jft.M ........'......1. 11...... . :== 1:=3~== '.-.. . '-... . '-... . :=::3 AM I"~ i" 7100 West(-)/East(+) [50ftlln] ¡J :.11 ¡i ¡¡Iii::-I"i'i:ì;i" 6650 6900 6950 7000 7050 ! , . . . .. , . . , . . . . . . , ", '.' ,-,-, ,., , ,.' I "[11 " 'i ¡ iil :¡i¡ l,i~Tnl 6100 6300 6350 6400 6450 6500 6600 6650 6700 6750 6600 Vertical Section at 92.00' [50ft11n] ::;~¡: ',..... ,..1 9500'--· :~i' !: 9550-'; -.. i'~,_:_ ~~.::-,.. !. ~. 19700-::,' 1'9750'':;'· : ICII ';. Ii 9600--:' Itu. .Æh'::¡ 985Q}. :. ::I 'é - .. ""> 9900-~ · . " i! 9950,: L.. " r- ,. 1 ??oo 10050 j 10100 '.¡ 10150-'} Company: Field : Site: Well: Wellpath: O··..···b ,j . p . Baker Hughes INTEe Baker Hughes INTEQ Planning Report BP Amoco Endicott End MPI 1-331M-23 Plan#5 1-33C1M-24 Field: Endicott North Slope UNITED STATES Map System:US State Plane Coordinate Geo Datmn: NAD27 (Clarke 1666) S15 Datum: Mean Sea Level Site: End MPI TR-12-16 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5979337.49 ft 256681.13 ft Riall 8JUlD ~S ...................-............. I~T£Q Date: 12/22/2004 Time: 15:43:14 Page: 1 Co-onllnate(NE) Reference: Well: 1-33/M-23, True North . Vertical (TVD) Refe.-ence: 11 : 09 12/911996 10:39 56.0 Section (VS) Reference: Well (O.OON,O.OOE.92.00Azi) SlU"Vey CakuJation Method: Minimum Curvature Db: Oracle Map Zone: Coordinate System: Geomagnetic Model: Latitude: 70 20 Longitude: 147 58 North Reference: Grid Convergence: Well: 1-33/M-23 Slot Name: 1-33/M-23 Well Position: +N/-S 3089.95 ft Northing: 5982350.76 ft Latitude: +FJ-W 2308.94 ft Easting: 259089.08 ft Longitude: Position Uncertainty: 0.00 ft Wellpath: Plan#5 1-33C/M-24 500292257703 ColTent Datmn: 11 : 09 1219/1996 1 0:39 Magnetic Data: 12/1412004 Field Strength: 57662 nT Vertical Section: Depth From (TVD) ft 41.50 Height 56.00 ft +N/-S ft 0.00 Plan: Plan #5 Land shallower in the K2B. Lower INC thru K2M. Principal: Yes Targets Annotation MD ft 11300.00 11350.00 11370.00 11524.25 11650.00 11852.62 11952.62 12222.62 12262.62 12462.62 12877.00 Name TVD ft 9447.79 9489.03 9505.64 9646.11 9764.89 9870.63 9872.34 9876.14 9876.53 9878.29 10131.30 Description Dip. Dir. TVD +N/-S TIP KOP end 9 DLS I begin 12 DLS 4 51 end 12 DLSI begin 32 DLS 6 1 end 32 DLSI begin 20 DLS 7 8 9 10 TO Plan Section Infonnation Drilled From: Tie-on Depth: Above System Datmn: Declination: Mag Dip Angle: +FJ-W ft 0.00 Date Composed: Version: Tied-to: +FJ-W Map Map Northing Easting Alaska. Zone 3 Well Centre bggm2004 38.358 N 30.505 W True -1.86 deg 33 70 21 8.744 N 147 57 23.020 W 1-33/M-23 11300.00 ft Mean Sea Level 25.34 deg 80.96 deg Direction deg 92.00 12/14/2004 3 From: Definitive Path <- Latitude -> <-- Longitude -> Deg Min See Deg Min . See MD Incl Adm TVD +N/-S +FJ-W DLS BuRd Tum TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 11300.00 34.20 110.31 9447.79 -1293.69 5584.10 0.00 0.00 0.00 0.00 11350.00 34.69 110.23 9489.03 -1303.48 5610.63 0.98 0.98 -0.16 354.69 11370.00 32.92 109.65 9505.64 -1307.28 5621.09 9.00 -8.86 -2.88 -170.00 11524.25 15.00 97.36 9646.11 -1324.08 5680.88 12.00 -11.62 -7.97 -170.00 11650.00 24.16 60.00 9764.89 -1313.24 5719.53 12.00 7.28 -29.71 287.46 11852.62 89.00 60.00 9870.63 -1233.11 5858.30 32.00 32.00 0.00 0.00 · Baker Hughes INT. Bit. Ob 8AK_ E,}. . P ~s Baker Hughes INTEQ Planning Report ................................. I~Vl£Q Company: BP Amoco 5 Date: 12/2212004 Time: 15:43:14 Page: 2 Field: Endicott Co-onlinate(NE) Reference: Well: 1-33/M-23. True North Site: End MPI Vertiad (TVD) Refereflce: 11 : 09 12/911996 10:39 56.0 WeD: 1-331M-23 Sedion (VS) Refe~e: Well (O.OON,O.OOE,92.00Azi) WeUpath: Plan#S 1-33C/M-24 Survey Cakulation Method: Minimum Curvature Db: Ora de Plan Section Infonnation MD Incl Aztm TVD +N/-S +F1-W DLS BuDd Turn TFO Target ft deg deg ft ft ft degl100ft deg/1001t deg/1001t deg 11952.62 69.06 40.00 9672.34 -1169.17 5934.51 20.00 0.06 -20.00 -90.00 12222.62 89.45 94.00 9876.14 -1067.55 6173.92 20.00 0.14 20.00 90.00 12262.62 89.45 86.00 9876.53 -1067.55 6213.89 20.00 0.01 -20.00 -90.00 12462.62 89.58 126.00 9878.29 -1121.56 6402.25 20.00 0.06 20.00 90.00 12877.00 6.71 126.00 10131.30 -1287.57 6630.73 20.00 -20.00 0.00 180.00 Survey Incl Azim SS TVD N/S F1W MapN MapE DLS VS TFO Tool deg deg ft ft ft ft ft deg/100ft ft deg 34.20 110.31 9391.79 -1293.69 5584.10 5980878.24 264628.51 0.00 5625.85 0.00 TIP ,"" 34.44 / 110.27 9412.44 -1298.57 5597.33 5980872.93 264641.57 0.98 5639.24 354.69 MWD ./.' 34.69 110.23 9433.03 -1303.48 5610.63 5980867.60 264654.71 0.98 5652.71 354.72 KOP ç 32.92 109.65 9449.64 -1307.28 5621.09 5980863.47 264665.04 9.00. 5663.29 ~ end 9 11375.00 32.33 109.46 9453.85 -1308.18 5623.63 5980862.48 264667.55 12.00 5665.86 90.00 MWD - 11400.00 29.38 108.38 9475.31 -1312.34 5635.76 5980857.93 264679.53 12.00 5678.12 190.16 MWD ,.." 11425.00 26.44 1 07.09 9497.40 -1315.91 5646.90 5980854.01 264690.55 12.00 5689.38 191 .09 MWD /; ~' 11450.00 23.52 105.49 9520.06 -1318.88 5657.03 5980850.72 264700.58 12.00 5699.61 192.24 MWD .J \Þ..(ft 11475.00 20.61 103.48 9543.23 -1321.24 5666.12 5980848.07 264709.59 12.00 5708.78 193.68 MWD 11500.00 17.74 100.84 9566.84 -1322.98 5674.14 5980846.07 264717.55 12.00 5716.85 195.55 MWD O. <to /"fI"1 11524.25 15.00 97.36 9590.11 -1324.08 5680.88 5980844.75 264724.26 12.00 5723.63 198.04 4 11525.00 15.03 97.03 9590.83 -1324.11 5681.08 5980844.72 264724.45 11.96 5723.83 287.26 MWD '( 11550.00 16.19 86.73 9614.91 -1324.30 5687.77 5980844.31 264731.14 12.00 5730.53 287.78 MWD 11575.00 17.78 78.00 9638.83 -1323.31 5694.99 5980845.07 264738.38 12.00 5737.70 297.69 MWD 11600.00 19.69 70.79 9662.50 -1321.13 5702.70 5980847.00 264746.16 12.00 5745.33 306.04 MWD 11625.00 21.84 64.87 ~~411 ;~ -r.~ek:t"1<. 264754.45 12.00 5753.40 312.88 MWD ~ 9685.88 -1317.77 5710.89 5980850.10 11650.00 24.16 60.00 9708.89 -1313.24 5719.53 5980854.35 264763.23 5761.88 318.41 51 en 11675:00 32.16 60.00 9730.92 -1307.34 5729.74 5980859.91 264773.63 5771.88 ~:bO 11700.00 40.16 60.00 9751.08 -1299.97 5742.51 5980866.87 264786.62 5784.38 0.00 MWD 11725.00 48.16 60.00 9769.00 -1291.27 5757.58 5980875.08 264801.96 5799.13 360.00 MWD tc:Þ 11750.00 56.16 60.00 9784.33 -1281.41 5774.66 5980884.39 264819.35 32.00 5815.86 0.00 MWD -I. 11775.00 64.16 60.00 9796.76 -1270.57 5793.43 5980894.61 264838.46 32.00 5834.24 0.00 MWD ."..~ I(t> 11800.00 72.16 60.00 9806.05 -1258.98 5813.51 5980905.56 264858.90 32.00 5853.90 360 .00 MWD 11825.00 80.16 60.00 9812.03 -1246.85 5834.51 5980917.00 264880.28 32.00 5874.47 0.00 MWD ~t: 11850.00 88.16 60.00 9814.57 -1234.43 5856.03 5980928.73 264902.19 32.00 5895.55 360.00 MWD 89.00 60.00 9814.63 -1233.11 5858.30 5980929.97 264904.50 5897.77 0.00 6/en 89.00 55.52 9815.02 -1221.18 5877.22 59B0941.28 264923.80 5916.26 270.00 MWD 89.01 50.52 9815.46 -1206.15 5897.19 5980955.66 264944.23 5935.69 270.08 MWD 89.03 45.52 9815.88 -1189.44 5915.76 5980971.77 264963.33 5953.67 270.16 MWD 89.06 40.52 9816.30 -1171.17 5932.81 5980989.48 264980.96 5970.07 270.25 MWD 11952.62 89.06 40.00 9816.34 -1169.17 5934.51 5980991.43 264982.72 20.00 5971.70 270.33 7 11975.00 89.06 44.47 9816.71 -1152.61 5949.54 5981007.49 264998.28 20.00 5986.14 90.00 MWD 'fI'''' 12000.00 89.07 49.47 9817.12 -1135.56 5967.81 5981023.95 265017.09 20.00 6003.80 89.93 MWD 12025.00 89.09 54.47 9817.52 -1120.16 5987.49 5981038.70 265037.25 20.00 6022.94 89.85 MWD ø 12050.00 89.11 59.47 9817.91 -1106.55 6008.44 5981051.64 265058.63 20.00 6043.40 89.77 MWD 12075.00 89.14 64.48 9818.29 -1094.80 6030.50 5981062.66 265081.06 20.00 6065.04 89.69 MWD 12100.00 89.18 69.48 9818.66 -1085.03 6053.50 5981071.69 265104.36 20.00 6087.68 89.61 MWD 12125.00 89.23 74.48 9819.00 -1077.30 6077.27 5981078.66 265128.36 20.00 6111.16 89.54 MWD 12150.00 89.27 79.48 9819.33 -1071.67 6101.61 5981083.50 265152.87 20.00 6135.30 89.47 MWD 12175.00 89.33 84.48 9819.63 -1068.18 6126.36 5981086.19 265177.71 20.00 6159.91 89.40 MWD 12200.00 89.39 89.48 9819.91 -1066.86 6151.31 5981 006...71 265202.70 20.00 6184.80 89.34 MWD '-12 , 89.45 94.00 '- 9820"14) -1067.55 6173.92 '~~ ~~22~ 20.00 6207.42 89.29 8 12225.00 89.45 93.53 ""9820:17 -1067.70 6176.29 598 .06 265227.63 20.00 6209.79 270.00 MWD 12250.00 89.45 88.53 9820.41 -1068.15 6201.28 5981083.81 265252.59 20.00 6234.78 270.00 MWD 12262.62 89.45 86.00 9820.53 -1067.55 6213.89 5981084.01 265265.21 20.00 6247.36 270.05 9 O·~···:\··b.! ....../'. r . Baker Hughes INT. Baker Hughes INTEQ Planning Report BiUIII 8AKH ~s ................................. INfE(} Company: BP Amoco 5 Date: 12/22/2004 Time: 15:43:14 Page: 3 Field: Endicott CCH)rdlnate{NE) Reference: Well: 1-33/M-23, True North Site: End MPI . Vertical (TVD) Reference: 11 : 091219/199610:39 56.0 Well: 1-33fM..23 SedJon (VS) Reference: Well (O.ooN,O.ooE,92.ooAzi) Wellpath: Plan#5 1-33CIM-24 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Inel Azim SS TVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 12275.00 89.45 88.48 9820.65 -1066.95 6226.25 5981084.21 265277.59 20.00 6259.69 90.00 MWD 12300.00 89.46 93.48 9820.88 -1067.38 6251.23 5981082.98 265302.55 20.00 6284.68 89.98 MWD 12325.00 89.47 98.48 9821.12 -1069.98 6276.09 5981079.58 265327.30 20.00 6309.61 89.93 MWD 12350.00 89.48 103.48 9821.35 -1074.74 6300.62 5981074.04 265351.67 20.00 6334.29 89.88 MWD 12375.00 89.49 108.48 9821.57 -1081.61 6324.65 5981066.39 265375.46 20.00 6358.54 89.84 MWD 12400.00 89.51 113.48 9821.79 -1090.56 6347.98 5981056.70 265398.50 20.00 6382.18 89.79 MWD 12425.00 89.54 118.48 9822.00 -1101.51 6370.45 5981045.03 265420.60 20.00 6405.01 89.75 MWD 12450.00 89.57 123.48 9822.19 -1114.37 6391.88 5981031.49 265441.60 20.00 6426.87 89.71 MWD 12462.62 89.58 126.00 9822.29 -1121.56 6402.25 5981023.97 265451.74 20.00 6437.49 89.67 10 12475.00 87.11 126.00 9822.64 -1128.83 6412.26 5981016.38 265461.50 20.00 6447.75 180.00 MWD 12500.00 82.11 126.00 9824.99 -1143.46 6432.39 5981001.11 265481.15 20.00 6468.37 180.00 MWD Å'''c. 12525.00 77.11 126.00 9829.50 -1157.91 6452.27 5980986.03 265500.56 20.00 6488.75 180.00 MWD 12550.00 72.11 126.00 9836.14 -1172.07 6471.77 5980971.25 265519.59 20.00 6508.73 180.00 MWD 12575.00 67.11 126.00 9844.85 -1185.84 6490.72 5980956.88 265538.09 20.00 6528.15 180.00 MWD 12600.00 62.11 126.00 9855.56 -1199.11 6508.98 5980943.03 265555.92 20.00 6546.87 180.00 MWD 4°1., 12625.00 57.11 126.00 9868.21 -1211.78 6526.42 5980929.80 265572.94 20.00 6564.74 180.00 MWD 1 2650.00 52.11 126.00 -g-aa26á' -1223.76 6542.90 5980917.30 265589.03 20.00 6581.63 180.00 MWD 12675.00 47.11 126.00 9898.88 -1234.95 6558.30 5980905.63 265604.06 20.00 6597.41 180.00 MWD ! 12700.00 42.11 126.00 9916.67 -1245.26 6572.50 5980894.86 265617.92 20.00 6611 .96 180.00 MWD 12725.00 37.11 126.00 9935.93 -1254.63 6585.39 5980885.08 265630.50 20.00 6625.16 180.00 MWD 12750.00 32.11 126.00 9956.50 -1262.97 6596.87 5980876.38 265641.71 20.00 6636.93 180.00 MWD 12775.00 27.11 126.00 9978.23 -1270.23 6606.86 5980868.80 265651.46 20.00 6647.17 180.00 MWD 1 2800.00 22.11 126.00 1 0000 .95 -1276.35 6615.28 5980862.42 265659.67 20.00 6655.79 180.00 MWD 12825.00 17.11 126.00 10024.49 -1281.28 6622.06 5980857.27 265666.29 20.00 6662.75 180.00 MWD 12850.00 12.11 126.00 10048.68 -128498 6627.16 5980853.41 265671.27 20.00 6667.97 180.00 MWD 12875.00 ~ 126.00 10073.32 -1287.43 6630.54 5980850.85 265674.56 20.00 6671 .43 180.00 MWD 12877.00 126.00 10075.30 -1287.57 6630.73 5980850.70 265674.75 20.00 6671.63 180.00 TO .71 I I , 1527 ~ 12 ?17 - 113"50 :;;:.- 1'¡:j b.; ~/c.. I~'t- 306 Kå .1'vk.. /22'1 S/,";"" h./~ END1-338 TREE: .,CAMERON W 5000 psi RT. ELEV = 56. WELLHE 3518" 5000 psi FMC SF. ELEV = 18. MAX DEV = 88 @ 12541' 10-314", 45.5#lft, '- HES 'HXO' SVLN I I L-80, BTC. CSG. ~ (3.813" MIN. ID) 1581' I I ~ ~ .. ~ W/SSSV MIN I.D. is 5013' 2.0" 4-1/2", 12.6#/ft, 13CR - NSCT tubing GAS LFT MANæEJ..S (HES-KBMGM) Note: ST MD ND VLV LÞ. TCH PORT DATE Inner Annulus Fluids And I 7 3945 3490 BK Stimulation Acid Must 6 6122 5235 BK Contain 5 7447 63(]2 8K Corrosion Inhibitors 4 8323 70Q1 ElK 3 918S 77D5 8" ~ 1DOS1 8381 8K 1 1 (J95E; 9099 8". Note: Tie back sleeve is not I I .- 4-1/2" 'X' NIPPLE I I ... (HES 3.813" ID) 11 099' Anchored c'-- :8 7-5/8" PACKER I 11110' I Baker CHP Tie back ~ - 111147' I ( TIW HB-Bp· T ) sleeve 3.125"10 .. .. 4-1/2", 12.6#/ft, L-80 TAILPIPE XO to 2-7/8 Liner 11155' 1----- 2.375" ID I 7-5/8" CSG-BTC, 29.7# - .... Top of window @ 11724' - - PERFOR,\ T¡ON SUMrN"RY REF lOG CLl-GR ON 02104199 ANGLE AT TOP PERF: Note: Ref~; te ProCLJcl~:if1 œ lor hlS:oric3J perf 03t3 SIZE SPF "'~TER'v'AL - DÞ, TE 1-11/16'" .: 12499 - 12539 0 .. KEY: 0 = OP~ I C = CLOSED I SQ2=SQUEEZED ~ 2-7/8" ST-lliner 2.441"ID Min. 10 @ XO = 2.375" PBTD I 12548' I 2-718" Float I ,--. ~ I I Collar 12549' TD TAG 12542' DATE REV BY COMMB.¡TS B'{)COlT UNIT 02112,'99 DAV INiTIAL co..R.ETION 1M:LL: 1·338 1L·24 02/20/99 œ INiTIALPERf' PERMiT No: XXXXXXX 1 O,'! 0104 iTLH FORMA T CúRRE.CTúN APi No: :50-029-22577-02 12/31104 ITLP 7-5JPj' CSG CORRECTION SEe T NR E BP Exploration (Alaska) RT. ELEV = 56.0' . SF. ELEV = 18.7' MAX DEV = 88 @ 12541' END1 33C T~ 4-112",CAMERONW5000psi _ W~EAD: 13 5/8" 5000 psi FMC 10-3/4", 45.5#/ft, L-80, BTC. CSG. I 5013' I .. . HES 'HXO' SVLN (3.813" MIN. 10) W/SSSV MIN 1.0. is 2.0" 1581' 4-1/2", 12.6#/ft, 13CR NSCT tubing Note: Inner Annulus Fluids And Stimulation Acid Must Contain Corrosion Inhibitors GAS LFT MANDRELS (HES-KBM GM) ST Me TVD VLV LAT PORT DATE 7 3946 3490 BK 6 6122 5238 BK 5 7447 6302 BK 4 8323 7001 BK 3 9185 7705 BK 2 10051 8391 BK 1 10956 9099 BK 4-112" 'X' NIPPLE (HES 3.813" 10) 1-33C Proposed Sidetrack 7-5/8" PACKER ( TlW HB-BP- T ) 4-1/2" 'XN' NIPPLE ( 3.80" 10 milled out) TOL 2 3/8" at 11140' md 4-112", 12.6#/ft, 11198' DPM TAILPIPE 11188' ELM TOL 3 3/16" at 11170' md 7-5/8" CSG-BTC, 29.7# Whipstock 11350' md------... 3 3/16" TCII L-80 drilling liner 11650' md Chemical cut 2 7/8" 11380' MD 27/8" CIBP 11430'md Top of TTRD window @ 11724' DATE 02112/99 02120/99 10/101'04 12/311'04 01107105 REV BY DAV DB ITlH ITlP IIAOJ COMMENTS INITIAL COMPLETION INITIAL PERF FORMAT CORRECTION 7-518" CSG CORRECTION proposed sidetrack 1-33C ENDlCOlT UNIT WELL: 1-33B I L-24 ÆRMIT No: XXXXXXX API No: 5O-O~22577-02 see T N R E BP Exploration (Alaska) RT.ElEV =56.0' . SF. ELEV = 18.7' " MAX OEV = 88 @ 12541' END1-33C TREE: 4-112" ,CAMERON W 5000 psi W EAO: 13 5/8" 5000 psi FMC 10-3/4", 45.5#1ft, l-80, STC. CSG. I 5013' I ... . HES 'HXO' SVLN (3.813" MIN. 10) W/SSSV MIN 1.0. is 2.0" 1581' 4-112", 12.6#/ft, 13CR NSCT tubìna L/;'~tr ~~H"" ~/v"""'~J 1-"j3c. LY (wt~-I1~ ~~7~-3.5? IO~1 l"I.ð~l. .g 5.'1 GAS LFT MANDRELS (HES-KBM GM) ST Me TVD VLV LAT PORT DATE 7 3946 3490 BK 6 6122 5238 BK 5 7447 6302 BK 4 8323 7001 BK 3 9185 7705 BK 2 10051 8391 BK 1 10956 9099 BK 'i, ~ $)I 1-33C Proposed Sidetrack /~~~~'-'- V. ~ 2 f 8 o..,uU rlN /Í2,f77 _1U:>'5oV32. - Z'37.S"~,) = \" ~ (øLi )!- / / r r/l.S6-III"IO YÚ1._ 2·3 7,S"~\ -= .1\..- /01.1 ï ,J ,/,_ L) o.onl ;¡¡poc:: $0 (~ /oz.., Mo;5 1/7/05 Top of TTRD window @ 11724' ~~ /,1 d.1 TOl2 3/8" at 11140' md TOl 3 3/16" at 11170' md - - ~ · <¡ Bbl Whipstock 11350' md ~ 3 3/16" TCII l-80 drilling liner 11650' md Chemical cut 2 7/8" 11380' MD 27/8" CISP 11430'md DATE 02/12/99 02120/99 1 0/1 0/0.4 12/31 /0.4 01107105 REV BY DAV DB /TLH ITLP MOJ COMMENTS INrTlAL COMPLETION INrTlAL PERF FORMAT CORRECTION 7-518" CSG CORRECTION proposed sidetrack 1-33C ENDICOTT UNIT WELL: 1-33B 1L-24 PERMIT No: XXXXXXX API No: 50-029-22577-02 SEC T N R E BP Exploration (Alaska) TERRIE L HUBBLE BP EXPLORATION AK INC "Mastercard Check" PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 89-6/1252 173 DATE~ 6A.~¡R06~.'.~. ..............~:6eC-$ ¡Cû.DO O~ . . ..... .... .. ....., . ro. ... DOLLAF\8- First National Bank Alaska . . . . ^"'ho'~.. AK ..5p,. . ~oP~ MEMO \, ~ IfYI- ~'-{ . ___ I:~· 2 5 2000(;OI:qq~"'llq;2 2 711' ~ 5 5(;11- O~ 7 3 . . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRlA TE LETTERJP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME me¡ 1-33C/I1-2J! PTD# 2oS- 00 c¡ ~ Development Service Exploration Stratigraphic CHECK WHAT ADD-ONS "'CLUE ". APPLIES (OPTIONS) MULTI Tbe permit is for a new wellbore ·segment of LA TERAL existing weD . Permit No, API No. . (If API number Production. should continue to be reponed as last two. (2) digits a function 'of tbe original API number. stated are between 60-69) above. Pll.,OT HOLE ]n accordance with·20 AAC 25.005(1), aU (PH) records, data and logs acquired for tbe pilot hole must be clearly differentiated In botb name (name on permit plus PH) .. and API Dum ber (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject ·to fuD EXCEPTION .' compliance with 20 AAC 25..0SS~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving 8 spa dng eX cepdon. (Company Name) assumes the liability of any protest to tbe spacing .exception tbat may occur. : DRY DITCH AU dry ditcb sample sets submiUed to tbe SAMPLE Commission must be in DO greater tban 30' .. sample intervals from below tbe permafrost or from wbere samples are fin. caught and ] 0' sample j¡Îter:vaJs tbrough target zones. .. ENDICOTT OIL - 220100 Well Name: _DUCK IS UNIT MPIJ-33C/M24 Program DEV Well bore seg 0 -- INC Initial ClassfType ------º.EY /1-01 L GeoArea 890 Unit 111450 OnlOff Shore Off ~ Annular Dispo~ 0 i ii Administration P~rmit fee attachep Y~s_ 2 _Lease _number _appropriate - - - - -- Y~s_ 3 _U_nlque well n_a[1le _and ol!mb_er - - - - - - - - - - - - _ _ _ _ _ _ Yes_ _ _ __ ~ - - - - - - - - - - - ~ - - - - 4 Well JQcated lna defined _ppol_ Yes_ - - - - - - 5 WeJUocated prDper _dlstance from driJling unitb9undary_ _ Yes_ - - ~ - - - 6 WellJQcated proper _dlstance_ from other wells_ Y~s_ 7 _Sufficient .acrea9-e_aYail.able indrilliog unjt_ Y~s_ 8 Jtdeviated, js weJlbQre plaUnc)uped _ - - - - -- Y~s_ 9 Qperator Only Clffected party _ Y_es _ - - - - - - 10 _O-perator has_3pprpprlate_b_ond inJorce _ _ _ _ _ _ _ _ _ _ _ _ _ _ ________Yes___ - - - - - - - - - - - - - - - - - - -- - - -- 11 Permit c<an be lS$l!ed wjthQut conservation order _ _ _Y~s _ - - - - - Appr Date 12 P_ermit can be lssl!ed wjthQut ac!mioistratille_3-pprpvaJ _ Yes_ - - - - - - RPC 1/11/2005 13 Can permit be approved before 15-day wait Yes . 14 WellJQcat~d within area and_strataauthorizec! byJnjectipo Ord_er # (puUO# hCP[1l[1leots) (For NA _ 15 _A)I wel)s-"'litÞip Jl4JlJile_area_of reyieW jd~otlfied (Fpr seNjc_ewe[l only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ - -, - - - - - - - - - - - - - - - - - ~ - - - - -- 16 Pre-producec! injector; pur.ationof pre--proPuGtion less than 3 months (For_ser:.vice well QnJy) _ _ NA 17 ACMP finding 9f Consistel1cy _ has been Jssued for_ tbis project NA _ -~ -- Engineering 18 _Col1ductor stritlgprQvided _ _ _ NA _ 19 _SJ.Hface _casJngprQtects_ all_known USQWs _ _ _NA 20 CMT vol adeql!ate_ to circulate on _cond_uctor & surfcsg _ _ NA - - - - - - - - - - 21 _CMT vol adequate_ to tie-in JQngstring to_sud csg_ _ NA _ 22 _CMT will coyer_aJl koownproductiye hQrizons _ _ Yes_ AdeQuate excess, 23 C_asing de_signs adequate fpr CoT, B _& permafrost _ _ Yes_ 24 Apequ.atetankageor reser:.ve pit _ _ _ Y~s_ CTDU. 25 Jfa_re-orill" bCls_a 10:403 fQr .abandonment be~o apPJQved _ _ Yes _ * 26 _Adequatewellbore_separatjo_n_pro-posed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes_ _ __ - - - - - - - - -- - - - - - 27 Jtdjverter required, does it meet reguJations_ _ NA Sidetrack. _ Appr Date 28 Dritliog fJuid program sc<hematic& equip Jistadequate_ Yes MaxMW12-ppg. _ _ WGA 1/12/2005 29 BOPEs,d_o_they meetreguJation _ Yes _ e 30 BOPEpress ratiog ap-propriCltEUest to_(put psig incommentS)_ Y~s_ Test tp40QOpsi.IIlISF' 3849 psi._ 131 Choke manifold compJies w/APl RP-53 (May B4L Yes_ 32 WQrk Will OcCUr withoutoperatjonsbutdQwn_ _ Yes. 33 Js presence_ Qf H2S gas prQQable. - - - - - - - Yes_ Max 1-12S 1200 ppm! 34 Mechanlcalcooditlon of wells within AQR yerified (for s_ervice welJ only) NA. - Geology 35 Permit cal1 be lSSl!ed wlo hydrogen s_ulfide rneaSUres . No_ . 36 _D_ata_preseoted on_ poteJltial overpres_sure _ZOnes _ _ . NA_ Appr Date 137 S~tsrnicanalysJs_ of shaJlow gas_zpoes_ NA. - - - - - - RPC 1/1112005[38 _Seabep _cOndit;P/1 survey (if Off-shp(e) _NA. 39 . CQntact namelpÞotleforweelsly progressreQorts [explQratory 9nlYl NA - - Geologic Date: Engineering Date Date Commissioner: Commissioner: ner lJjs J IZ) 1- ß~.s-