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Home My WebLink About204-025 · . 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. ~ Q 4- - 0 d..$" Well History File Identifier D Two-sided 1111111111111111111 Organizing (done) D Rescan Needed 111111111111111111I RESCAN ~olor Items: ~reYSCale Items: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, NolType: D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: NOTES: Date / a::t 1/ / 0 " D Other:: Project Proofing 11111111111111 111I1 k14f BY: ~ /5/ BY: ~ Date: lei-WI Db /5/ ~ Scanning Preparation BY: -L x 30 = 30 + tQ = TOTAL PAGES '+~ I ~t does not include cover sheet D~: ~ ~ Production Scanning Stage 1 Page Count from Scanned File: 5'" 0 (Count does include c~r sheet) Page Count Matches Number in Scanning Preparation: V YES BY: G9 Date: ,~! II/Ora Stage 1 If NO in stage 1, page(s) discrepancies were found: YES 111111111111111111I NO /5/ V11 P NO BY: Maria Date: /5/ III 1111111111111111 Scanning is complete at this pOint unless rescanning is required. ReScanned 11111111111I111111I BY: Maria Date: /5/ Comments about this file: Quality Checked III /111111111111111 10/6/2005 Well History File Cover Page. doc • • . ~_ ~., MICROFILMED 03/01/2008 DrJ NOT PLACE ~rv ~~: ~~~ F~ _. ~~ ANY NEW MATERIAL UNDER THIS PAGE F:~LaserFichelC~~rPgs_Inserts~Microfilm Marker.doc '" - TOTAL €&P USA, INC. . November 18, 2004 GSRlALSKl098-04 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Cancellation of Permit to Drill #2040250 for Total Caribou 09-11 #1 Dear Mr. Norman, TOTAL E&P USA, Inc. hereby requests that the Alaska Oil and Gas Commission cancel the Permit to Drill #2040250 for Total's Caribou 09-11 #1. This permit was approved on February 6, 2004 and is not scheduled to expire until February 7, 2006. Total's current plans do not include the drilling of this well. If you have any questions or require additional information, please contact me at (713) 647-3680. Sincerely, TOTAL E&P USA, INC. ~~9 Alaska Manager RBDMs 8Fl NOV 2 3 7nn4 o TOTAL 800 Gessner, Suite 700, Houston, TX 77024-4284 Tel 713 647 3000 - Fax 7136473003 . . FRANK H. MURKOWSKI, GOVERNOR A1tASKA OIL AlQ) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501·3539 PHONE (907) 279-1433 FAX (907) 276·7542 Jean-Francois Prost Drilling Manager Total E&P USA, Inc. 4300 B Street, Suite 303 Anchorage, AK 99503 RE: Caribou 26-09 #] Exploratory Total E&P USA, Inc. Permit No: 204-025 Sur. Loc. 4038' FEL, 2406' FSL, Sec. 9, T9N, R5W, UM Btmhole Loc. 4038' FEL, 2406' FSL, Sec. 9, T9N, R5W, UM Dear Mr. Prost: Enclosed is the approved application for permit to drill the above referenced exploration well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. Annular disposal of drilling wastes will not be approved for this well until sufficient data are submitted to ensure that the requirements of20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, subsequent LOT data following setting production casing, and any CQLs must be submitted to the Commission on form ] 0-403AD prior to the approval of disposal operations. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. In your application, it is indicated that it may be necessary to stimulate the productive intervals in the well that may be tested. When plans are determined, a Sundry Application (Form 403) detailing the planned testing should ~ submitted for approval. BY ORDER OF T DA TED this o air COMMISSION ::rj-../ day of February, 2004 ith 20 AAC 25.035. Sufficient notice st be given so that a representative ofthe Commission petroleum field inspector The blowout prevention equipment (BOPE) must be tested in accor an (approximately 24 hours) of the diverter function test an PE s Commission may witness the tests. Notice may b lve tin on the North Slope pager at 659-3607. cc: Departmen ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. · STATE OF ALASKA . ASKA Oil AND GAS CONSERVATION ~MISSION PERMIT TO DRILL 20 AAC 25.005 tð/~ 1a. Type of Work: Drill o Redrill 0 1 b. Current Well Class: Exploratory 0 Development Oil 0 Multiple Zone 0 Re-entry 0 Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone 0 2. Operator Name: 5. Bond: Blanket 0 Single Well 0 11. Well Name and Number: TOTAL E&P USA, Inc. Bond No. RlB-0006700/ Caribou 09-11 #1 3. Address: 6. Proposed Depth: ./ 12. Field/Pool(s): 4300 B Street, Suite 303, Anchorage, Alaska 99503 MD: 9 669' ./ TVD: 9,669' Wildcat , 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 4038' FEL, 2406' FSL, Sec 9, T9N, R5W, UM f AA-084163 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: Same NSB 04-061 2/25/2004 Total Depth: 9. Acres in Property: 14. Distance to Nearest Same 11476 Property: 7,686' N 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Surface:x- 602423 ,. . Zone- (Height above GL): 29 feet Within Pool: 4 miles SW y- 5,904,446 ASP 5 16. Deviated wells: Kickoff depth: N/A feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: N/A degrees Downhole: 5,983 psi Surface: 1,881 Dsi ,/ 18. Casing Program: Specifications Setting Depth Quantity of Cement Size Top Bottom c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 20" 16" 65# H-40 PEB 80' 29' 29' 109' 109' Permafrost cmt to surface 12-1/4" 9-5/8" 40# L-80 BTC 2,990' 29' 29' 3019' 3019' 288 sx PF, 259 sx G 8-1/2" 7" 26# L-80 BTC 9,640' 29' 29' 9,669' 9,669' 125 sx G lead, 143 sx G tail 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Structural _.,.- 6",,> r-' 1\ II r"\ Conductor f't:.vL-! V I ¡.... ~../ Surface " ^' <'\f'I A Intermediate JAI~ .:J \1 ,"-UI Production .. - " ,...- r mnl11~,Sm!\ Liner AI ~S"ø \JII ''!t ""... Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee l:'J BOP Sketch ~ Drilling Program ~ Time v. Depth Plot~ Shallow Hazard Analysis l:'J Property Plat 0 Diverter Sketch [] Seabed Report 0 Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Bill Penrose 258-3446 Printed Name Jean-Francois Pros! dJ ~ Title Drilling Manager (~ U,/ , t4 Ó'" Signature Phone 743-0970 Date ...'d Commission Use Only Permit to Drill ¿j AP~ iber: Permit Approval Vt; t/ See cover letter for other Number: 20' - Ó2.~ 50- 279- 2C;()/O ~OO Date: t·A requirements. Co,dillo", of app,"'" . :~ f í!i" œ Yes ! No 0 Mud log required Yes ~ No ~ Hy e sulfi sures Yes No 'Ø Directional survey required Yes 0 No Other: ~ 0:þ~ ;¡; :r~/1L~ 6;~1:J :5 urV~~t~· BY ORDER OF Approved by: -.,-./ A / ~ IH£ CpMMISSION Date: /"'111/1; ?/ '--" ~ ORI6\NAL -. I Form 10-401 Revised 12/2003 Submit inDuplicate . STATE OF ALASKA . ASKA OIL AND GAS CONSERVATION ~MISSION PERMIT TO DRILL 20 MC 25.005 1a. Type of Work: Drill 0 Redrill 0 Re-entry 0 1 b. Current Well Class: Exploratory [] Development Oil 0 Multiple Zone [] Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone 0 5. Bond: Blanket 0 Single Well 0 11. Well Name and Number: Bond No. RLB-0006700 Caribou 09-11 #1 6. Proposed Depth: 12. Field/Pool(s): MD: 9,669' TVD: 9,669' Wildcat 7. Property Designation: AA-084163 8. Land Use Permit: NSB 04-061 9. Acres in Property: 2. Operator Name: TOTAL E&P USA, Inc. 3. Address: 4300 B Street, Suite 303, Anchorage, Alaska 99503 4a. Location of Well (Governmental Section): Surface: 4038' FEL, 2406' FSL, Sec 9, T9N, R5W, UM Top of Productive Horizon: Same Total Depth: Same 4b. Location of Well (State Base Plane Coordinates): Surface:x- 602423 y- 5,904,446 Zone- 16. Deviated wells: Kickoff depth: Maximum Hole Angle: ASP 5 feet degrees 13. Approximate Spud Date: 2/25/2004 14. Distance to Nearest 11476 Property: 7,686' N 10. KB Elevation 15. Distance to Nearest Well (Height above GL): 29 feet Within Pool: 4 miles SW 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: Surface: Weight Grade Coupling Length MD TVD MD TVD Quantity of Cement c.f.orsacks (including stage data) 18. Casing Program: Size Hole Casing Specifications Setting Depth Top Bottom PUBLIC INFORMATION COpy 19. Total Depth MD (ft): PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Structural Conductor Surface Intermediate Production Liner Length Size Cement Volume MD TVD Perforation Depth MD (ft): Perforation Depth TVD (ft): Filing Fee ~ BOP Sketch l.:::J Property Plat [] Diverter Sketch [] 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is tr~e and correct to the best of my knowledge. 11 Ii .k Jean-Francois ~ '1fTj /.//.. (// V Commission Use Only API Number: Permit Approval 50- 2- 79 ~ 2CJC.:J/6 - DO Date: Drilling Program l.:::J Seabed Report 0 Time v. Depth Plot l.:::J Shallow Hazard Analysis ~ Drilling Fluid Program [] 20 AAC 25.050 requirements D Date Contact Bill Penrose 258-3446 20. Attachments: Printed Name Title Drilling Manager , Signature Phone 743-0970 Date \\~ 1)~ Permit to D~ /'v / ,/ Number: A/7 ,--625' Conditions of approval: See cover letter for other requirements. Samples required Hydrogen sulfide measures Yes 'g'j No D Yes 0 No ~ Mud log required Yes ~ No D Directional survey required _ ,Yes q No 13*' ~tnA--hh.v <h'\b-~w-~ BY ORDER OF THE COMMISSION Date: Other: Approved by: Form 10-401 Revised 12/2003 Submit inDuplicate . . TOTAL Caribou 09-11 #1 Overview and Timetable TOTAL E&P USA, Inc. plans to drill an exploratory 'well, the Caribou 09-11 #1, in NPRA this winter. Caribou 09-11 # 1 will be located approximately 54 miles west of the village of Nuiqsut. The well will be drilled from a temporary ice pad with spudding estimated to occur approximately February 25, 2004. The well is planned as a straight hole. The well will be accessible via aircraft to Inigok, then ice road across the ITozen tundra and via rolligon from Meltwater 2P Pad. A map showing details of the ice road route and rolligon route as well as the drilling location are enclosed in this application. Ice road and pad construction will begin as soon as the necessary permits and approvals are available and weather conditions allow. It is planned that the Caribou 09-11 #1 ice road will extend approximately ~4miles to the west ITom the north-south ice road that currently connects Inigok and the C"anbou 26-11 #1 drilling location. Construction of the ice road and ice pad will occur while Caribou 26-11 #1 is being drilled. Upon completion of the ice drilling pad and the drilling of Caribou 26-11 #1, Nabors' Rig #14-E will be moved to the Caribou 09-11 #1 wellsite. The rig will be supported with personnel and light supplies flown into Inigok and transported to the wellsite via the ice road. Heavy supplies and equipment will be brought overland via rolligon. ~ V{ ell testing may be perf0l'!!!t::d. Current plans are to plug and abandon the well prior to the end of the 200312004 winter drilling season; however, the well may be temporarily shut in and secured if well evaluation cannot be completed prior to the closing of tundra travel in the spring of 2004. If the well proves to be a dry hole, it will be plugged and abandoned at the end of this field season. If the well is to be tested, it will be completed, a tree installed and the rig released. If there is time for testing, the well will be tested and, if promising, shut in until a following winter season. If there is insufficient time for testing, the well will be shut in and tested during a subsequent winter season. In either case, if the well test is insufficiently encouraging, the well will be plugged and abandoned without a rig at the conclusion of testing. - ....",. .... ...,"-' ~-"-"----'-~"-- ~,......,,'> Operational Considerations Permafrost Based on offset wells, permafrost is assumed to be present from the surface to approximately 600'. The permafrost is not expected to present any drilling difficulties as neither thawing nor gas hydrate problems were encountered in any of the offset wells. Surface Casing Shoe Depth The 3,019'RT setting depth for the 9-5/8" surface casing is located in the bottom 200' of the Lower Nanushuk sands, just above the Torok shale." The casing shoe will be set in a . . competent shale within the Lower Nanushuk in order to yield a strong shoe test, yet leave some of the Nanushuk sand exposed between the casing shoe and the Torok shale for later annular injection of waste drilling fluids. , Lost Circulation and Sloughing Shales Some of the offsetting wells encountered sloughing shales below the HRZ and lost circulation in and near their target horizons. The Caribou 09-11 #1 casing and mud programs have been designed to take these potential problems into account. While the preferred well design presented here calls for a long string of 7" casing to be set at TD, an alternate well design is included in this Application wherein intermediate casing is set just above the target horizon to isolate sloughing shales and the mud weight cut to avoid lost circulation in the target interval. When TD is reached, the target interval will be evaluated as an open hole or, ifhole conditions dictate, cased with a production liner. Pressures Anticipated pore pressures are derived primarily from the histories of offsetting wells. These wells, referenced in the Pressure section of this application, were all drilled in the past few years and are well-documented. As shown on the attached pore pressure plot and maximum anticipated surface pressure (MASP) calculations, the highest expected V" pressure is at 9,400' and is 5,817 psi (11.9 ppg EMW) and will result in a maximum pressure at the surface, with a full column of gas, of 1,881 psi (see enclosed Maximum Anticipated Surface Pressure calculations). A 5,000 psi WP BOP and wellhead system will therefore be used on this well. Abnormally pressured shallow gas is not anticipated. The pore pressure prediction section of this application contains an evaluation of the risk of drilling high-pressure zones as potentially recognized after seismic processing. An abnormal pore pressure gradient starts near the top of the HRZ (~8,021' SS) that may explain their tendency to slough. Drilling Within Annular Blowout Preventer Limitations As shown in the attached pore pressure prediction study, the highest pressure expected above the surface casing setting depth (8.9 ppg equivalent mud weight at 3,019' TVD less a 0.11 psi/ft gas gradient) is 1,065 psi which is within the 2,000 psi working pressure rating of the diverter. Below the surface casing, BOPs will be used in lieu of a diverter. Again, the MASP calculations show that all anticipated surface pressures are well below the 5,000 psi working pressure rating ofthe annular preventer. BOP System and BOPE Testing The BOP system on Nabors Rig #14-E is rated at 5,000 psi working pressure and is described in the BOPE section of this application. Since the calculated maximum anticipated working pressure (at the surface) in this well is 1,881 psi, it is planned to routinely test all BOPE to 80% of its rated working pressure (i.e., 4,000 psi). . . The BOP system will be tested initially (before spudding the well) and weekly thereafter to a low pressure of 200 psi and a high pressure of 4,000 psi (80% of rated working pressure). Straight Hole The Caribou 09-11 # 1 will be drilled as a straight hole.' Directional control will be monitored via MWD in all hole sections. H2S None of the offsetting wells encountered measurable amounts of H2S in the intervals to be drilled at Caribou and it is not expected that Caribou 09-11 #1 will encounter any. However, the drilling rig will be wired with operating sensors, enhanced by additional sensors tied into the mud logging system, to continuously monitor for the presence of . H2S. Also, the wellhead and tree will be trimmed for H2S service. Drilling Waste Handling Waste drilling mud from the well will be pumped into subsurface formations at ~/ approximately 3,000'DF via the 9-5/8" surface casing X 7" intermediate casing annulus. Cuttings will be hauled to an approved disposal facility for processing and disposal. Prior to on-site disposal or hauling, mud and cuttings will be temporarily stored in a bermed storage cell on the ice pad or in appropriate containers. Diagrams are included with this application that show the ice pad layouts with the proposed location of the storage cell. Additional Information Additional information on operations such as formation tops, logging, mud logging, etc. . can be found on the attached Caribou 09-11 #1 Well Prognosis. Certified Location Plat An as-built location plat, certified by a Registered Land Surveyor, will be submitted shortly after construction of the drilling location is completed and the conductor set. Contacts The contacts within TOTAL for information are: Reporting and Technical Information Jean-Yves Bellanger (907) 743-0970 Geological Data and Logs John Johns (713) 647-3435 Well Name: Surface Loc.: Target Loc.: Bottomhole Loc.: Elevations: Planned TD: Formation Tops: Cores: Planned Logs: . TOTAL Caribou 09-11 #1 Well Pro2:Dosis TOTAL Caribou 09-11 #1 . 4036' FEL, 2406' FSL, Sec. 9, T9N, R5W, UM ./ Same as surface location (straight hole) Same as surface location (straight hole) Ground Level 190' AMSL Rotary Table (RT) 29' AGL 9,669' TVD, 9,669' MD (RT) TOPS Colville Gp. Conglomerates Nanushuk Sands Torok Shale "A" Base of Slope Sands Lower Torok Shale "B" Base of Slope Sands HRZ LCU I Valanginian Shale MFS Warm Shale Val. Channel FilII Alpine Sand BCU I Kimm Silt Oxfordian Shale TD DEPTHS (SS. TVD) Surface 1,250' 3,000' 5,600' 6,000' 7,100' 8,021 ' 8,277' 8,890' 9,040 ' 9,203 ' 9,403' 9,450' , One 90' core may be taken in the target sands. 12-Y4 Surface Hole. 110'-3.019'RT L WD: GrlResistivity 8-112" Production Hole. 3.034' - 9.669'RT LWD: GrlResistivity Wireline: GR - Res- DenslNeutron, Dipole Sonic v Optional Rotary SWC Mud Logging: . . Mud logging will be in operation from the base of the 16" conductor to TD. Service will include sample collection, ROP, lithology, show description, hot wire, gas analysis of cuttings, gas chromatography, and drilling parameters. Thirty-foot (30') samples will be collected from the base of the surface casing, and 10-foot (10') samples will be collected in zones of interest. The well site geologist will adjust the interval or sample frequency as required. Planned Sampling 1 set unwashed each: Total 3 sets washed and dried: Total 1 set washed and dried: Partners (2), State of AK, BLM 1 set canned ditch samples for geochemical analysis collected at 30' intervals from base ofthe conductor casing toTD. . . ALASKA - NPRA Caribou East Caribou 09 - 11 #1 Geologic Prognosis Surface Location: 4036' FEL, 2406' FSL, Sec. 09, T09N, R05W, UM if 70 deg. 08 min. 53.77 sec. N 153 deg. 10 min. 35.58 sec W (NAD 27) X = 602,423' Y = 5,904,446' (Alaska State Plane 5) . Ground Level: -190 feet ./ Est. Top "Alpine Sand" Primary Reservoir Objective: -9,040' SS TVD ~ Proposed "Alpine Sand" Location: 4036' FEL, 2406' FSL, Sec. 09, T09N, R05W, UM 70 deg. 08 min. 53.77 sec. N 153 deg. 10 min. 35.58 see W (NAD 27) X = 602,423' Y = 5,904,446' (Alaska State Plane 5) Proposed Total Depth: -9,450' SS TVD Proposed Total Depth Location: 4036' FEL, 2406' FSL, Sec. 09, T09N, R05W, UM 70 deg. 08 min. 53.77 sec. N 153 deg. 10 min. 35.58 see W (NAD 27) X = 602,423' Y = 5,904,446' (Alaska State Plane 5) GEOLOGICAL HAZARDS & OBJECTIVES The well will initially drill through the Colville Group Conglomerate section starting at or near surface. The base of the permafrost will be reached within the middle of the conglomerate. Pore pressure prediction from seismic (Brilliant Geoscience, Inc., August 2003) indicates a possible anomalous pressure increase below the./ base of the permafrost (approximately 1000 feet below MSL). This shallow pressure increase has been noted in the local well control, and drilling mud weights ranged between 10 and 10.5 ppg./ ,/ Within the Nanushuk topset sands, isolated gas filled sand bodies may be present. Our pore pre~sure prediction does not indicate a Nanushuk over-pressured sand at our location, but the possibility cannot be ruled out. The well is expected to be normal pressured from the Nanushuk to near the top of the HRZ Shale. Our pore pressure prediction indicates an increase in pressure from the top HRZ until TD. This over-pressured section ,," should have pressures of approximately 0.52 psi/ft. Being slightly overpressured, the shale section has a tendency to wash out and shows up on caliper logs throughout the North Slope. In particular, Conoco-Phillips has had severe problems with the MFS shale section, located directly on top of the primary objective. The MFS will potentially cave in and grab drill pipe. Having to set intermediate pipe within the Valanginian shale is a possibility. TIME FORMATION DEPTH (msec.) LITHOLOGY /« Colville Group Congl. @ surface Conglomerates Potential Base of permafrost gas sands Nanushuk Sands -1,250' SS Sand Pot. Isolated Gas sands Torok Shale -3,000' SS 95% Shale Top of "A" Base of -5,600' SS Sand Stringers Pot G/Gs sands Slope Sands Lower Torok Shale -6,000' SS Shale/Sand stringers Top of"B" Base of -7,100' SS Sand Stringers Pot G/Gs sands v ./ Revised 10/14/03 . . TIME Notes FORMATION DEPTH (msec.) LITHOLOGY > Slope Sands HRZ -8,021' SS 1.639 ms Black Shale Top Pressure LCU! Val. Shale -8,277' SS 1.686 ms Shale MFS Warm Shale -8,890' SS Shale Washes out Top Val. Channel Fill / -9,040' SS 1.839 ms Sand / Silt Alpine Sand Top BCD / Kimm. Silt -9,203' SS 1.868 ms Silt Top Oxfordian Shale -9,403' SS Shale TD -9,450' SS Shale Still in Pressure Y" " OPEN HOLE EVALUATION 1. Mudloqqinq: ", Mudloggers will be rigged up and operational at the spud of the well. They will monitor the well from surface to TO. 2. Conventional Corinq: One 90 foot conventional core may be taken in the "Alpine Sand" ¡/ (-9,040' SS TVO), the primary reservoir objective of the well. 3. LWO: LWO services (GR/Res) will be utilized on this well in the 8.5" hole section (9.625" casing to TO). Additional equipment may be added if required by the drilling department. 4. Wireline: One wireline log job is planned for this well over the 8.5" hole section (from TO to the 9.625" casing shoe). Run 1: NGT-Res-Oen/Neu-OSI Run 2: MOT (optional) Run 3: FMI-CMR (optional) Run 4: VSP/Checkshot (optional) Run 5: Rotary Sidewall Cores (optional) 2 Revised 10/14/03 PERIOD Potential Hazards Albian? Aptian? Barremian Valcmginian Formation, Lithology, Colville Group Conglomerate Nanushuk Lower Torok Slope "B" I PERIOD Cenomanian? Albian? Aptian ? Hauterivian , ,:1<'" " ' I, ' "",', I " -, , . '" ~', " , . ", " ; ~OI RaW" , , ""',,", ' '" ',' , I, " , , ," 1 , , " ,- ":, 1_' , -:f , i I . ' , " , i : ",,, :, ) , '- -:- \ ' T·" - ~'", " , , ' , ,', ~ ", ,y. "',, y . '. /" , I " , LL -I :\1 r, /1; ( ; }¡! N I) . I·' , ~ ~ ,I. , ',- I"~ 1 '" ',,' ',' - , I :1." , , " [ ",' \:: . '", .; , ,', ': ~ .." TIC , , "< '- 'I ,,', I ' 4 ~. , "I , , ~ '.";' -~ I . IC" T7N:m: ' , ',. , ' -; T .: I ROLLIGON RDUJr::.n1lJ ROUTE ~, 04 :Mll'1B' ICE ROAD RO rl'l''j'J.!,'l} WA ,- SOUHCE I I E&P Inc. IJi: J1 ,crR CT , ' ",: .' I!I!I"" ¿f- ~ s ,'" , , , I }' , , 7" '" " " , 'ff' -'" ~ ,,' rmJ 1 ' ""," I , I, , " .' I ' ·rÞ ' . , ' , \' , - ,i -- , I : '" ' ! ' ," I , ,I I ,,~I\ " I , , I , I T I l --, EXPLORA fit " ' '''" '., I , , . I 'j ", :, , .. . ,', ,TI"'" ,'" , I" :. . , -- . iïrœ\ ' i! ,,,' 1 , .' ' , , , " TSN Ræ _~' 1 TI N ' , , , , , '" ", ", : , 1 . I . " ;''',.., 1 , , -, ': I - - . '" \ ' I TSN~ " I," ". :, , , ·,1 w,,,» i., " , \- ~ ,- I , '. ,I ,,: \ '",...... ". ' " '/," " , .. I , " " ~'ì" I·, ~ ''''', \ ,~ F" :' , '. ~, , , " , , ., - " I , "'. , ,,' , I" i I 1°1°° ° 219°0 GRAPHIC SCALE míitl QJMW¡'¡;: BURT "'" 1 0-28-03 1'- AS' NOTED ~, {\ - r-¡, -" -, , ,I A'f1.J,SIl , ".,'" , I TSN¡~æ\ 1",' ,,', \"" , I "',, , r ' , ¡I" , , I \ r . , "', . ,,' " , ." ! .' I ' , , : .\ : "" """, ,iT -'... ,...., . , , . . , , - I -+1 , , ' ' ¡ J" , , " \ ., IVI II!!!!I& n IlctA _ ". '¡¡¡ ROLUGON ROUTES BETWEEN KUPARUK ¡;" -j'"' M::; AND CARIBOU EAST ïl·1V!:)I""'C!.,; I it ¡"'''''TOTAL lfJ&P NPR-A I""" I TOTAL-I NPR-A 2003-2004 EXPLORATION FIG 8-2.ÐWG "~.----~----'-~_._._--------~-~ --~~ T10N R6W T10N R4W T9N R7W T8N R7W TaN R6W ~.~~._- PO SITE 04 -.-- J ~. 'ì WATPR SOURCE TO FIG. 3-1 PROPOSED ICE ROAD / ROLLlGON ROUTES AND WATER / ICE CHIP SOURCES CARIBOU PROSPECT AREA 13000 I 1_~)OOO' AS NOTED EXPLORATIOIV FIG 3 j,DWG ¡...·-Aï:iSKÄ-·i:ÏËÑrw...l \SPfl.L(B~~r\ ¡ 20IJV SINGt£ PH4S£ I i___~J!!IIIfif!I__J 5lJO'-0· \~ ß CASING , ~ ~ BASKETS t ' ~~ ~ & MUD , .. / 'P ~ STORAGE ~ ICE PAD/ . 'Q e:?~~ LIMITS ~ DRILL ~ ~ ~ 'V PIPE ~~ '® BASKETS' ~ ~ 200'-0 \\~ ,...-""'\ ~~ ~~ ~' \ . ~' . . \ ØI: " Gf. \ ~... , ,ø- _............ S'tO~"(f.v.' \. ' ~ ~ ~' . ~t'GS ~f.v.\'" , ~ \ c\S ~~f.O ~ ' \ \9'i' , , . \ ~ \-~' NABORS ALASKA RIG 14E RIG PLACEMENT EXPLORATION CONFIGURATION CONCEPTUAL PAD LAYOUT NORTH 0' ~I u; I f/ èI! ~-J ~113' ;!/ C/J! I il :sl ~I ZJl/AIIJ, A JA. .... '12' 5I/IJI1fmD LAIWI' ro JUTN. Fr/A EJF 'W' .......... . I:-\\) /~ TOTAL . . -Na6oIsAt.llrr =-C'=t'="~ "'. A....___.... ~=-~ RB5OJ-2I31 NABORS AlASKA RIG 74£ RIG PtAcatfNT ÐlPl.ORATION CONFIGURATION COHCEPTIJAL PAD LAYOUT ; of , 1 o 10 15 20 5 Spud · Caribou 09-11 #1 Drilling Program NPRA Alaska 2003-2004 Drilling Season e ø TOTAL Caribou 09-11 #1 Drilling Procedure 1. MIRV Nabors rig 14E over pre-installed conductor casing. Attach landing ring to conductor. 2. Install diverter and function test. Notify regulatory agencies 48 hours prior to test. 3. Spud well and drill 12-1/4" hole to the surface casing point at 3,019' RT. Run and utilize MWD tools throughout this hole section to monitor hole angle and to ensure hole remains vertical. 4. Condition hole for casing. POOH. 5. Run and cement 9-5/8", 40#, L-80, BTC casing to surface. Employ a lightweight permafrost cement lead slurry followed by a high strength Class G tail slurry pUI1lE-ed viaQrill pipe stabbed into the casing shoe. Pump adequate excess cement to ensure cement reachesthe sui-lace. - 6. Nipple down diverter and nipple up BOPE. Test BOPE. Notify regulatory agencies 48 hours prior to test. 7. Make up an 8-1/2" drilling BHA and RIH to the top of the 9-5/8" float equipment. Pressure test the casing to 3,000 psi for 30 minutes. Record the pressure test and fax the results to Anchorage. 8. Drill the float equipment and 20' of new hole. Perform a LOT (or FIT if the gradient exceeds 16 ppg EMW). Record the results and fax to Anchorage. 9. Drill an 8-1/2" straight hole to the top of the Alpine Sands at ±9,259'RT, looking for core" point. Run L WD logging tools in the drill string as required for formation data gathering.> 10. At the coring point, POOH and PIU coring assembly. RIH. 11. Take one 90' core in the Alpine interval. POOH. 12. Rill with the same 8-1/2" drilling assembly used previously, ream the cored interval, and continue drilling 8-1/2" hole to TD at ±9,669'RT. 13. Condition hole for logging. POOH. , 14. Rig up wireline. Run wireline formation evaluation logs per logging program.' Rig down wireline. If the decision is made to plug and abandon the well, proceed to Step 23. 15. Make a cleanout run to condition the hole for running casing. POOH. 16. Run and cement 7", 26#, L-80, BTC casing at ±9,669'RT TD. Pump sufficient cement to bring the top to ±6,900' RT. TOC should not be allowed to approach the 9-5/8" casing shoe because the 7" X 9-5/8" annulus will be used for annular injection of mud. 17. Make a cleanout run with bit and scraper. 18. Displace well to brine. 19. Run and land 3-1/2" tubing completion. Pressure test tubing and annulus and freeze protect both. 20. Nipple down BOPE. Nipple up production tree and test to 5,000 psi. 21. Secure well and release rig. 22. MIRU well testing equipment and surface test tanks. Perform production tests as required. Produced fluids will be injected back into the formation. 23. Upon completion of testing or if the well is not completed, plug and abandon the well per applicable regulations. Thoroughly clean location and access road. Nabors Alaska Spud: 20" Hole 16",65#, H-40, Casing @ +/- 109' Base Permafrost at +/-600' of 12 1/4" Hole 9-5/8 ,. Casing @ +/- 301 ' 9 5/8" I Note: All referenced depths MD/TVD RF I 8 1/2" Hole @+/-6,800' (Approx. middle Top of tail slurry@ +/-8,969' (+/- 300' above top of 7" @ 9,669 Bill Penrose ·' . TOTAL E&P USA, Inc. Pressure Calculations and Drilling Area Risks Caribou 09-11 #1 Maximum Anticipated Surface Pressure: The maximum anticipated surface pressure (MASP) for this well will be the lesser of the formation pore pressure (less a full gas column to the surface) at TD or the formation fracture pressure at the last casing shoe (less a full gas column to the surface). Based on the attached study "Pre-Drill Seismic Pore Pressure Prediction For Location #6", the highest formation pressure expected in the final hole section is 5,817 psi at a depth of approximately 9,400' TVD (or 0.619 psi/ft).!/Documented fracture gradient data for this area indicates that the fracture gradient at 3,019'TVD (the 9-5/8" surface casing shoe) is a minimum of 0.733 psi/ft (14.1 ppg). Complete evacuation of the wellbore, except for a 0.11 psi/ft gas gradient, is assumed. 8-112" hole section MASP (pore pressure) MASP (fm breakdown) (9,400 ft)(0.619 - 0.11) = 4,785 psi (3,019 ft)(0.733 - 0.11) = 1,881 psi.¡ Therefore, MASP in the 8-112" open hole section is 1,881 psi and the 5,000 psi BOPE system to be used will be adequate. Well Proximity Risk: The nearest wellbore to that of the Caribou 09-11 #1 is the Caribou 26-11 #1 test well located approximately 3.5 miles to the northwest. There are therefore no nearby wellbore proximity risks. Drillin2 Area Risks: See attached Drilling Hazard Summary. Disposal of Muds and Cuttin2s: Drill cuttings will be stored in bermed holding cells or appropriate containers on the ice pad and hauled to an established processing facility in one of the oil fields to the east at the conclusion of drilling operations at Caribou. Excess drilling mud will be hauled to an existing field to the east for disposal until the 7" casing is set, then the excess mud will be ',. disposed of by being injected down the 9-5/8" x 7" annulus. .¡ .' CARIBOU 09-11 #1 DRILLING HAZARDS SUMMARY 12-1/4" Hole / 9-5/8" Casin2 Interval EVENT RISK LEVEL Miti2ation Strate2V Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Low If observed - control drill, reduce pump rates, reduce drilling fluid temperatures, additions of Lecithin. Gravel/Sand Sloughing to 500' Moderate Increase mud weight/viscosity, High viscosity sweeps. Monitor fill on connections Hole Swabbing/Tight Hole on Moderate Circulate hole clean prior to trip. Proper hole fill Trips (use of trip sheets), pumping out of hole as needed. Possible thaw bulb/water flow Low Watch return viscosity for signs of thinning. Increased mud weight/viscosity as needed. Lost Circulation Low Prevent by keeping hole clean. Reduce mud weight if practical. If losses occur - reduce pump rates and mud rheology, use LCM ^?" 8-1/2" Hole / 7" Casin2 Interval Event Risk Level Miti2ation Strate2V Shale stability in MFS interval Moderate Control with higher MW and proper drilling below HRZ practices. May be necessary to set 7" casing across shales in order to proceed. Lost Circulation Moderate Monitor hole cleaning. Reduced pump rates, mud rheology, LCM. Barite Settling Low Good drilling practices as documented in well plan. Differential Sticking Low Periodic wiper trips. Do not leave pipe static for extended period of time Abnormal Reservoir Pressure Moderate / Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills, increased mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. ",,,, Caribou 09-11 #1 Casin2 Properties and Desi2n Casing Performance Properties . ~ . Internal Collapse Tensile Strength Size Weight Yield Resistance Joint Body TVD MD Design Safety Factor* (in.) (lb/ft) Grade Cnxn úW úW (1,OOOlbs) ( ft R T) ( ft R T) T B C 9-5/8 40 L-80 BTC 5,750 3,090 979 916 3,019 3,019 8.83 3.06 2.90 7 26 L-80 BTCM 7,240 5,410 667 604 9,669 9,669 2.96 3.85 1.13 * Tensile design safety factors are calculated using pipe weight less buoyancy. Burst design safety factors are calculated using Maximum Anticipated Surface Pressure. Collapse design safety factors are calculated assuming complete evacuation of the casing. Casing Setting Depth Rationale . 9-5/8" 3,019' RT, MD Surface casing to provide an anchor for BOP equipment and sufficient fracture gradient until the reservoir is reached. Production casing to provide hole stability and pressure containment for production testing operations. It also provides an annulus down which to inject waste mud. 7" 9,669' RT, MD .1 . Formation Intee:ritv Test (FIT) and Leak-Off Test (LOT) Procedures Note that the terms used in the procedures and the spreadsheet ofFITILOT results are defined as follows: · Formation Integrity Test (FIT) - Formation is tested to a pre-determined equivalent mud weight. · Leak-Off Test (LOT) - Pressure is exerted against the formation until fluid begins to discernibly pump away. Pressure at which this first occurs is the leak-off point. · LOT Limit - 16.0 ppg EMW for all surface casing shoe tests; determined from previous experience with formation breakdown problems by attempting higher leak-offs. · Open Hole LOTs (OH LOTs)- Leak-off tests performed with open hole from the casing shoe to some point above the target reservoir. Generally done when leak-off is required but could not be achieved just below the casing shoe; or where weaker formations are suspected above the target reservoir but below the casing shoe, and assurance is required of being able to achieve estimated mud weight. Procedure for FIT: 1. Drill 20' of new hole below the casing shoe. 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drillpipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in I-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Formation integrity tests are conducted on all casing shoes with the exception of some surface casing situations. Where annular pumping will be done on a well, the formation below the surface shoe is taken to leak-off. This ensures that future disposal fluids can pumped away without risk of damage to the surface shoe. If two attempts at establishing leak-off at the shoe are unsuccessful (using 16.0 ppg EMW LOT limit per definition above), then an open-hole LOT is performed. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. . . Pre-Drill Seismic Pore Pressure Prediction for Location #6 Alaska State Plane 5 X=602,423 Y=5,904,446 August 27, 2003 Summary Pore pressures likely to be encountered at the proposed #6 well location are predicted using the seismic velocity data. The normal compaction trend and translation model are derived from the Hottman- Johnson methodology and utilize local well control (Hunter A, North Inigok #1, Inigok #1). The compaction trend and translation model were applied to velocities from 2D seismic data through the well location to predict pore and fracture pressures. The data show possible anomalous pressure increases at approximately 1000 feet below MSL (below the'" base of permafrost) and at 7100 feet below MSL near the top of the HRZ. The shallow predicted pore pressure increase has also been noted in the local well control (drilled with' 10-10.5 lb./gal mud weights). The HRZ anomaly seems to be consistent with higher pore pressures and accompanying mud weights as seen in the local well control, although the magnitude of the predicted pore pressure in the wells exceeds the pressure observed in the wells, suggesting that the predicted pore pressures associated with the HRZ might be /' somewhat exaggerated. Seismic Processing The precision of the pore pressure prediction is directly related to the quality of the seismic velocity field. The velocities used for pressure prediction were generated from Total's proprietary Deltastack software. This software produces an accurate, continuous velocity analysis (every cdp and each time sample) and outputs both VRMS and DIX (interval velocity) sections. The Dix velocities were smoothed to minimize instability in the velocity field which could result from variation in CDP fold or noise. Pressure Prediction Procedure Brilliant Geoscience Inc. of Dallas utilized PPFG software (developed by ARCa Exploration and Production Technology) to calculate the predicted pore pressures and fracture pressures. The Hunter A, North Inigok #1 and Inigok #1 gamma ray and sonic logs were used to establish a local normal compaction trend in the shale intervals. Second order polynomial functions were used to translate the ~DT (difference between seismic ITT and DT from the compaction trend) to pore pressure gradients. Where PPG = Co + C1 *( ~(~T)) + C2* (~( ~T))**2 . . In this area, the coefficients are Co = .465; C1 = .0062; C2 = 1.34 e-5 Fracture gradients were calculated using the Eaton methodology. Overburden pressure, calculated pore pressure gradient profiles, and Poisson's Ratio profiles are the inputs. Seismic Pore Pressure Prediction Pore pressure gradients were predicted along a 2D seismic line (Line 304 in Fig. 1 ) through Location #6. Pressure gradient prediction displays are provided in depth with the depth stretched seismic wiggle trace overlay (Fig.2). The higher predicted mud weights (pore pressure gradients) are represented by the warmer colors as indicated on the scale on the right hand side ofthe display. Two potential high pressure zones were observed. An increase in predicted pore pressure is observed starting at approximately 1000 feet below MSL (Fig.3.) In order to capture the shallow part of the low velocity anomalies (which translate to high PPG values), Brilliant Geoscience Inc. started the calculation from 1000 feet. This is not their standard practice because the number of seismic traces available for the velocity analysis is lower and the velocity derived from seismic data is subject to noise in this shallow depth range. Even so, it should be noted that the seismic data also predicts an increase in pore pressure in the same interval in the North Inigok #1, Hunter A, and Inigok #1 wells and this zone was drilled with 10-10.5 lb/gal mud weights in these wells ( Figs. 4-6). An increase in pore pressure is also predicted near the top of the HRZ horizon at approximately 7100 ft below MSL (Fig.3). Mud weights used to drill this zone in the North Inigok #1, Hunter A, and Inigok #1 support this observation, although the magnitude of the predicted pore pressure increase from the seismic data at these wells (in lbs/gal equivalent mud weight) is larger than the mud weights observed in the wells. Conclusions 1. There is an apparent increase in pore pressure at 1000' below MSL, below the" base of the permafrost. . . 2. There are similar anomalies in this zone predicted by the seismic at the North Inigok # 1, Hunter A , and Inigok # 1 and their presence is supported by the mud weights used in the wells. 3. There is an increase in predicted pore pressure near the top ofthe HRZ at 7100 ft . below MSL. 4. A moderate increase in pore pressure was seen at the top of the HRZ in the North Inigok, Inigok and Hunter A wells. This zone may have a lithology element in addition to a compaction disequilibrium. because the seismic velocities predict a higher pore pressure than was apparently seen in the wells. 5. The normal compaction trend observed in the North Inigok, Inigok, and Hunter A wells is a good match for the seismic derived normal compaction trend. Line NW 1 pressu radient iction ~ dQ' ¡: "'! ~ W N.IN 1 Well u Analysis ~ rRi' ¡::: "'I ~ tit INI 1 Well Seismic ~ dQ' c: "'! !'t> Q\ . . BOP Control System The BOPE control system on Nabors Rig #14-E is an NL Koomey Model 40200-3S blowout preventer control unit with a 202-gallon volume tame Main energy is provided by a 40 HP electric motor driven triplex plunger pump rated at 20.2 gpm at 3,000 psi. The pump charges twenty (20) eleven-gallon bladder-type separator accumulators. A second energy charging system consists of two Model 31-00103 air pumps rated at a combined volume of 11.0 gpm at 1,200 psi, or 7.2 gpm at 3,000 psi. The above two energy systems are backed up by six 220 cubic foot nitrogen bottles connected to the manifold system. All of the systems are controlled by a Model SU2KB7 series manifold with seven manual control stations at the unit. I, IINERÆR ~_r - 2. _~1MI.1£ _r aœm .& && IINERÆR -. 11'/ 21 '/4"-2OIXJP5I fINoŒS" [ .& DIVERTER CONFIGURATION - . / VAL\'[ - ;¡~DD' l"'" ::=n . .~.! r- ii ii O~ 40D10 8 ~ I- ~.J. vy .....!:f _^^ . D~. 't: j\ i\ V - Ie · ~ Jõ '~ firR .,'j H JIt[. \ I V tJ ~ 2 1111 I . III h , 'xl Iç~ 1 ,/\, I ! \ \i\/\/ - , ii \/ .! ï X t, i\ í ì / \ ,--, . . , , r--1 I 1\/\/\ - II ~ ~I mr::zI Ir I I -r . ~ / .IU~ æ I ;x: \, ~l -, ..~ t i = í IlIIIIIIIIIII a:::o _ 1\ . rf && IS" IMIIIER ~ "- . IT! \ - .& - ~ \ 16" KIH~ - ~ "'04'_ III!"' ~ 1 1 1 ~ ~ r-- - 1 I l l .11. " ~ ~ \ ~ ~ .~ '_'0 24fE899 C lð0EC92 8 ISMMI2 A PM DIIAIIIHG OIH.OII 5 DIll '1:' NABORS ALASKA RIG 14E DIVERTER LINE LAYOUT 14" OPERATOR HYDRIL 13-5/8" 5k PSI GK ANNULAR BOP SCREW HEAD FlANGED BOTTOM CONNECnON 54-1/8" LENGTH KILL LINE #1 3" 5k GATE VALVE 3" 5k HeR VALVE 3" 5k CHECK VALVE 3-1/16" 5k FLG x 2" 5k UNIBOLT AmNG REFERENCE KILL UNE 12 FOR ALIGNMENT 14" OPERATOR HYDRIL 13-5/8" 5k PSI HYDRAUUC RAM SINGLE GATE FlANGED CONNECnON 36" LENGTH BLIND SHEARS . 18' 10" OPERATOR 10" OPERATOR HYDRIL IJ-5/8" 5k PSI HYDRAULIC RAM SINGLE GATE .. FlANGED CONNECnON J6" LENGTH 4" PIPE RAMS DRIWNG SPOOL IJ-5/8" 10k BUND FlANGE 4-1/16" 5k (CHOKE SIDE) 4" 5k HCR VALVE I~ 4" CHOKE LINE 4" 5k GAlf VALVE KILL LINE #2 10" OPERATOR --------L------- I 10" OPERATOR HYDRIL IJ-5/8" 5k PSI HYDRAUUC RAM SINGLE GATE FlANGED CONNEcnON J6" LENGTH 3·1/2" x 6" VBR's BUND FlANGE DRIWNG SPOOL IJ-'5/8" 10k J-1/16" 5k (KILL SIDE) . J-1/16" 5k FLG x 2" 5k UNIBOLT ATTING 3" 5k CHECK VALVE . ..- BLOWOUT PREVENTOR STACK ."",.... . ---.... ..--- 2S2SC _ _ zoo ~--- CONFIGURATION NABORS AI.ASI<A /I/C 14£ /KIP STACK CONf/GIJ//AT'ION . IO/OJ A M. D.H. IIO/JIREl STICK ctJNf1(;(JRAT'ION -;« AU'IIW I'" ãilt1SØll......... "/14\'£ IÐERT ,.... A r- "'''I' "'If' - 1-- /jAI~2Ot/.J1-- 14£...11III»-2 I""; of I NABORS ALASKA RIG 14E " . Caribou Drilling Program NPRA Alaska 2003-2004 Drilling Season . o TOTAL Caribou 09-11 #1 Cementing Program 9-5/8" Surface CaSiDi! (Set at 3.019') Spacer: 50 bbls water Pre-Flush: 50 bbls, density 10.2 ppg Lead Slurry: Top of slurry: Surface Permafrost Cement, density 10.7 ppg Excess: 250% across permafrost interval from surface to 1200' 30% in open hole between 2,400' and base permafrost Yield: 4.15 cu ft/sk Volume (including excess): 213 bbls (288 sx) Tail Slurry: Top of slurry: 2,400' Class G + 2% Calcium Chloride, density 15.8 ppg Excess: 30% in open hole Yield: 1.15 cu ft/sk Volume (including excess): 53 bbls (259 sx) . Caribou Drilling Program NPRA Alaska 2003-2004 Drilling Season . o TOTAL 7" Production Casin2: (Set at 9.669' TD) Spacer: 5 bbls water Pre-Flush: 25 bbls, density 10.2 ppg Lead Slurry: Top of slurry: 6,800' (middle of Lower Torok) Class G + 15% light weight extender + 0.2% friction reducer + 0.75% fluid loss additive + 0.05 glsk anti-foam + retarder as required. Density 12.5 ppg. Excess: 30% in open hole Yield: 2.36 cu ft/sk Volume (including excess): 52.3 bbls (125 sx) Tail Slurry: Top of slurry: 8,681' (±300' above top of Alpine Sands) Class G + 0.6% latex polymer + 0.5% friction reducer + 0.05 glsk anti- foam + retarder as required. Density 15.8 ppg. Excess: 30% in open hole Yield: 1.16 cu ft/sk Volume (including excess): 30 bbls (143 sx) - 2 - . Caribou Drilling Program NPRA Alaska 2003-2004 Drilling Season . o TOTAL Caribou 09-11 #1 Drilling Fluid Program The TOTAL Caribou 09-11 #1 will be drilled ftom surface to TD using a low-solids, non-dispersed, inhibited 6% KCI/polymer mud system. The well will be spudded using a 10.0 ppg high-viscosity spud mud to aid in cleaning the shallow portion of the hole where surficial gravels are anticipated. After setting the 9-5/8" surface casing at approximately 3,019', the mud system will be treated to lower the density, solids content, viscosity and otherwise adjusted to drill the remainder of the hole with a high quality mud suitable for handling the potential problems of sloughing shales and/or lost circulation. It is not anticipated that any wholesale change-outs of the mud system will be performed at any point because disposal of the old mud system could be problematic. Planned drilling fluid properties are as follow: Interval (FtT) ~VV Surf - 3000' 10.0 - 10.5 3000'-7000' 9.5 -10.5 7000'-TD' 10.0 -12.5 Vis 75 - 95 45 - 55 45 - 55 PV 25 - 30 15 - 20 15 - 25 YP 35 - 45 10 - 20 15 - 25 API VVL 5 -15 5-7 3-5 Cuttings will be retained in a bermed cell on the ice pad or in appropriate containers and later hauled to one of the established fields to the east for processing and disposal. However, waste drilling fluid will be retained in liquid form on location until the 9-5/8" x 7" annulus becomes available, whereupon the waste mud will be injected down the annulus. Since the most common and most significant hole problems experienced in the offsetting wells were those of lost circulation and sloughing shales, adequate supplies of LCM and shale inhibitors will kept on location. Also, an adequate barite supply will be maintained to weight up the mud system in response to any need to control unanticipated pressure. Finally, while H2S is not anticipated in this well, the remoteness of the location dictates that a supply ofH2S sequestering agents be maintained on location. DERRICK 20 fNE OESILTER ~ ii .~ ~i U~il (3) DERRICK ~ ONE 000IC0 SHALE SHAKERS 1!3 1110O· '2J, ~ ~2(J(J{) '-' '~i~ 1\ fl fl { fllfl rh fl fl ( fl f'\ <t I FLOWUNE &. I ~ i I i ! I i I --c~1 5'B CENlRlFUGf hflflflflflflf'\f'\f'\r f'\0J flfl &. fll" ¡;, h n ~~wœ ----- FROAI wo CVN ~ 0fWSE0 fDUCroRJET ~=L~ ~~ i ~I ¡j" ~¡;, ~I ¡; ~i !~I\ ~ ~i ~I ¡;, ~'" if+=11/IP ''f: ": \ &. .... .... 7511I' &. /RIP TANK PUW 4x6 G4UGHER IS!> -----.J .. ~ ~ &. w .~. ~ y IIUO,SJ.,.... '" ~ñOOL. &. fOR IJ£GASSINjJ ....y DESAI/lJER PUMP GAUGHER 4X6 C!) roHDl£FIU.& 75 HP MUD ClEANER PUMP GALlGHER 1\ 4X6 0 75 HP CASING FlU. UNfS CENTRIFUŒ PUMP MISSION 1 1/2 X 2 IItIOCI.fANfR SCRHNEJ) UNDfRflOW s 12'" ,"","",,1.1I£ o ~ I ~ UNDf1/f/1J(( ~ l~ PO' ,.... 226.6 B8I.. ! &. I y'wAm¡. .. ·1 IIUD 222.9~PIT ROU.-F1U. LM , , , ¡ ,--. I /NJfCfIÖN TANK1· T 169.0 ='-FI1. UNf . , , , , , , NABORS ALASKA RIG 14E MUD SYSTEM SCHEMATIC 1000 BBL ACTIVE SYSTEM WITH DEWATERING UNIT I· . . I ~ !Ii ~ 1 ¡.. ~ ..1 ì,~.r lOON< '" ~~ 148.5 BEl. l!:3 1 ~~: 1. ~i it &. &. CHARGf PUMPS GAUCHER 4 X 6 75 III' TO OILWELL A-17ooPT MUOPUMPS LINE JLlNO &. PM DRAWING 004.0206 - - 75 HP ;:~ &. ~m - - f9WR PKJNfER ~ WO HOPÆ1IS "iJ L T '.1 ,~:: 1. T T T[ G4UGllER __ HOPPER 1\ 4x6'S '1ì GUN PUMP J 0 PUMP 75 HP ----<+- l,uyOJ C JA 19 t«NQI B R:Ii' - - - I E~NAL &. TANK ----- FLOCCULANT INJECTION CRlSAFUW PUMP ~ MUOWGUN I UAIIIFOLD . ~ c::J. ~rofJ1CJ1SPOSAL ~tHD ,:: TANK 6: BL 180 ~ J I~ ro~ ~f -. I ~ ~ I~ 1 I ~= 100 B8l 70 ER L - -- ~ SUCTION de DISCHARGE W AUXILiARY TANKS OR VACUUM 1RIJCKS ø~.4:':.. PROdErr ADDED IUtf> DEÆ.. Ðr. G4LXõfQ RBI. BtICIŒT tn TIllE /iÐtSlD I4ÆCfION PWP NID DRNNS RfIfCMD 20 ,JI 01 A JA G'OYÆRŒD IJLIMN'i JO WO Fl.HMT Dl'TE 'Iï'~~ DESCRPI10N ""'-' Total Caribou 9-11 #1 (Site 6) permit . . Steve, I am forwarding the geophysicists shallow seismic comments on our Caribou 9-11 #1 (site 6). For your reference, the site 2 mentioned is the Caribou 26-11 #1 we are presently drilling. If you have any additional questions, feel free to call. best regards, Jonn tf.1I. Jonns Total E&P USA, Inc. Office: (713) 647-3435 john.johns@total.com ----- Forwarded by John JOHNS/HOU/US/EP/Corp on 02104/2004 06:41 PM ----- Mike HOI To: John JOHNS/HOU/US/EP/Corp@E&P 02/04/2004 04:41 PM cc: Subject: Site 6 Shallow anomalies John, I've just looked at our 3D lines over site 6 (along with the other sites also) and did not see any shallow amplitude anomalies. In comparison with site 2, the seismic reflectors near the top of the Nanushuk sands are slightly stronger at site 6 than site 2. Mike 1 of 1 2/5/20048:51 AM [Fwd: Filing Fee for TOTAL Caribou APD] . . Steve, Some information for the latest Total application. Tom -------- Original Message -------- Subject: Filing Fee for TOTAL Caribou APD Date: Mon, 02 Feb 2004 07:32:48 -0900 From: Bill Penrose <bill@fairweather.com> To: Tom Maunder (tom maunder@admin.state.ak.us) <tom maunder@admin.state.ak.us>, Winton Aubert (Winton Aubert@admin.state.ak.us) <winton aubert@admin.state.ak.us> CC: Jack Bergeron (jack.bergeron@total.com) <jack.bergeron@total.com> Tom & Winton, On Friday, January 30, I delivered to the AOGCC offices an Application for Permit to Drill TOTAL's Caribou 09-11 #1. Through an oversight of yours truly, the mandatory $100.00 filing fee was not included with the APD. This is to inform you that TOTAL is aware of this (after receiving a call from a Commission representative) and a check is being cut in TOTAL's Houston office and will be sent up shortly. Regards, Bill 1 of 1 2/2/20049:46 AM . TOTAL E:&P USA, INC. . January 30, 2004 Acting Chair Alaska Oil and Gas Conservation Commission 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 RE(.;EIVED JAN 3 () 2004 (> r"I',:{..· .. Comm'~$!On Alaska /:< _u Anchmage RE: Application for Permit to Drill: TOTAL Caribou 09-11 #1 Dear Sir, TOTAL E&P USA, Inc. hereby applies for a Permit to Drill an onshore exploratory'" well in the NPRA area of the North Slope. The well, called the Caribou 09-11 #1, will be located approximately 54 miles west of the village of Nuiqsut and 10 miles north of the Inigok #1 test well. TOTAL plans to spud Caribou 09-11 #1 approximately February 25, 2004. Ice road/pad construction equipment will be mobilized to the existing Caribou 26- 11 #1 drilling location. Then, upon receipt of all necessary permits and approvals, an ice road will be constructed extending approximately 4 miles to the west from the north-south ice road that currently connects Inigok and the Caribou 26-11 #1 drilling location. The drilling rig, Nabors 14-E, will then be mobilized via truck from the Caribou 26-11 #1 location to the new drilling location, the well drilled to TD and tested if log results warrant. The rig will be demobilized via rolligon. Pertinent information attached to this application includes the following: ~ '-'- TOTAL 1) Form 10-401 Application for Permit to Drill (Public Information) - 1 copy 2) Form 10-401 Application for Permit to Drill - 2 copies 3) Fee of $100.00 payable to the State of Alaska 4) Well Prognosis and discussion of Operational Considerations 5) Location Plat and Drill Pad Layout 6) Days vs. Depth Drilling Curve 7) Drilling Procedure 8) Well bore and Wellhead Schematics 9) Pressure Information including pore pressure, mud weight and v fracture gradient curves, offset well mud weight curves, maximum anticipated surface pressure calculations, FIT and LOT procedures, and casing properties and design factors. 10) Diverter, BOP and choke manifold schematics 11) Cement Program 12) Drilling Fluid Program 4300 B Street, Suite 303, Anchorage, AK 99503 Tel 907 743 0970 - Fax 907 7430979 1] R t G \ N A L . TOTAL £&P USA, INC. . January 30, 2004 Page 2 of 2 As part of this Application, TOTAL also requests approval for the annular <;"'- injection of drilling wastes as discussed in the attachments. The AOGCC is requested to keep confidential all information included in the Application for Permit to Drill (except the Public Information copy) as information in these documents is drawn from research and data proprietary to Total. For your information, this permit request is being simultaneously submitted to the U.S. Bureau of Land Management. If you have any questions or require additional information, please contact me at (907) 743-0970. Sincerely, TOTALE~~.,i~ { Ar . v:' ~ "'/,,, , ¿/'" ì Jean-Francois Prost Drilling Manager Enclosures ~ "-" TOTAL 4300 B Street, Suite 303, Anchorage, AK 99503 Tel 9077430970 - Fax 907 743 0979 <41( REMOVE THIS STUB BEFORE CASHING 2 M 80434-1( THE FRONT OF THE DOCUMENT HAS A MICRO-PRINT AMOUNT BOX AND THERMOCHROMIC. ABSENCE OF THESE FEATURES ~vlq~.JNDICATr;:r\ COPY. . INTERNATIONAL ' MONEY ORDER . , ,,', TravelersExpressMoneyGram . . PAY TO THE ORDER OF: i\ , / ", " ~" l'- ,\~/ lei , \i!"j " t, ,~,,"" "'\:\) ~" '''-1,:'' 'L" í F" >., \"), \ <: D'\ ì (~ ,- " L, t ",- ç l ,It)" \, "i,li \~ PURCHASER, SIGNER FOR DkAWER: PURCHASER, BY SIGNING YOU AGREE TO THE SERVICE CHARGE AND OTHER TERMS ON THE REVERSE SIDE ADDRESS: ~ ')-i,' ( t~\···~~~;.( ", Payable Through ' Wf National Bank South Central faribault, MN y~., ',:,j. (.;:,,1,,' -;'-t \ , " t;' i {'\c:. '~ Ì< t "..I.;", I", ," r -,l. \. , ISSUER/DRAWER, TRA VELERS EXPRESS COMPANY, INC 1:0 Ii . C¡OO 5 j :}ø: L. :JaB 2 0 B 5 c~ ? JJ 0 n8 75-53 9T9 §;'v"~\CATi',,,~ ~U¡' qO . . TRANSMJT AL LETTER CHECKLIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMI.TT AL LETTER . 4- . WELL NAME ~rl bo~ 09 r/! I PTD# ;;2Ot./ -o¿~ Q.,~~t.XG..\'VO'0- ~Cé \\ CHECK WßA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (Jf API num ber last two (2) digits are between 60-69) s<'d~. :]0 ~ - \ <=t Co "CLUE" The permit is for a new weHbore segment of existing well . Permit No, API No. . Production should continue to be reported as a function of tbe original API number stated above. HOLE In accordance witb 20 AAC 25.005(1), an records, data and logs acquired for tbe pilot hole must be dearly differentiated in both name (name on permit plus PH) and API Dumber (50 - 70/80) from records, data and logs acquired for we)) (name on permit). P~OT (PH) SPACING EXCEPTION / DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject ·to fuD compliance witb 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 tbat may occur. All dry ditch sample sets submitted to tbe Commission must be in no greatertban 30' sample intervals from below tbe permafrost or from where samples are first caught and 10' sample intervals througb target zones. PTD#: 2040250 Administration o ~ Appr Date SFD 2/3/2004 Engineering Appr Date TEM 2/4/2004 Geology Appr SFD Date 2/5/2004 Field & Pool Well Name: CARIBOU 09-11 1 Program EXP Well bore seg Company TOTAL E&P USA, INC Initial ClasslType EXP 1 PEND GeoArea 890 Unit OnlOff Shore On Annular Disposal 1 Permit feEt attached. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . No. . 1/30/Q4; Notified ofJack .of fee by L. .Laasçh. .2L210~; EmaiJ saying çhe.cl< is.in the maiJ. .SFD.. ....,. 2 ,LeasenumbeJ apprOPJiate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Yes. . . . . . . feder.al NPM lease . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3 ,Uni~uEt well,n,ame .aod lJu.mber , _ . . . . . . . _ _ _ _ , , . . . . . . _ _ , , . . . . . . _ _ _ , . . . .Yes _ _ , , . . . . . , _ _ , , , . . . _ _ _ _ _ . . . . . . . _ _ . . . . . . _ _ _ . , . . . . . _ _ . _ , . . . . . _ _ _ _ . . . . . _ , . . . . , , 4 WeJlJo,cated iRa.d.efined P.ool . . . . . . ... . . . . . . . . . NA . . . . . . . Exploratory well. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ...... . . . . . . 5 WeJIJocated pr.opEtr dislanceJrom driJling unitb.oundary. . . . . . . . . . . . . . . . . . . . .Yes. . . . . . . . . . . . . . . . .. ....... . . . . . . . . . . . . . . . . . . . . .. . . . . . . . . . . . 6 WeJl.lo.cated proper di$lanceJrorn. otheJ wells. . . . . . . . . . . . . . . . . . . . . . . . . . .Yes. . . . . . . IIIEtarEtst welLis Carib.ou 26-11 #1. ~ 3 rnJles to NE. . . . . . . . . . . . . . . . . . . . . 7 ,SIJfficient acreage.available in.drilJilJguniL . . . . . . . . . . . . . . . . .. ....... .Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ....... . . . . . . . . . . . . . . . . . . . . . 8 Jf.deviated, is weJlboJe plaUncluded . . . . . . . . . . . . . . . . . . . . . . . NA . . . . . . . VEtrtical weJI. . . . . . . . . . . . . . . . . . . . . . . . . . .. ......... ......... 9 pper.ator only affected party. . . . . .. ....... . . . . . . . . . . Yes ....... . . . . . . .. ...... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10 Pperalor has,appr.opriate.b.ond ill Jorce. . . . _ _ _ ' . . . . . . . _ _ ' , . . . . . . . _ _ _ . . . . . .Yes. , . . . . . . . , ' , . . . . . _ _ . , . . . . . . _ _ ' , . . . . . _ , _ ' , , . . . . , , , _ . . . . . . . _ _ ' . . . . . . _ _ , . . . _ _ . 11 Permit can be i.ssu.ed witho.ut co.nSEtrvation order. . . . . . . . . . . . . . . . .Yes. ....., .. . . . . . , . . . . . . . . . . . . . . . .. ...... . . . . . . . . . . . . . . . 12 Permitcao be i$su.ed without administratille.approvaJ '.. . . . . . . . . . . . . Yes . . . . . . . . . . . . . . . , ' , , , . . . . . . . . . . . . . . . . . . . . . , . . . . . . . . . . . . . . . . . . . 13 Can permit be approved before 15-day wait Yes 14 WeJI Jocated within area an,d.strata autborized by.lojecti.olJ Order # (puUO# inc.ommeots).(For. .NA . . . . . , . . , . . . . . . . , . , . . . . . . 15 All wells.witbin.1£4,mile.are.a.of review ideotjfied (F.or.servicewelJ onl}1, , . . . . . . . _ , , . . . NA _ _ , . . . . . . . . _ , . . . . . _ , _ , , . . . . . . _ _ _ , . . . . . . _ _ . . . . . . . . _ _ . . . . . . . . _ _ , . . . . . . . ' . . . . _ 16 Pre.-produœd.iojector; duratio.n.ofpre-producti.onless.tban3mollths.<For,selYiœwell.only)., NA................. ,....,.................... .....,.,............... 17 ACMP.FJn.dingof Con$isteOGY.has bEtenJs.suEtdJor.tbis proiect. . , ' . . . . . . . . . . . . No, ..... .1Ç..Laughlin, JPO,.121S/03:No.Review .Required for TotªI'$expIQratory ddlljng thiswjntEtr.. . . . . . . . . . . 18 .c.ooduçt.or strjn.Q,provided . . . . . ' . . . . . . . , . . . . . . . . . . . . . . . . . . . . , . . . . .Yes. . . . . . . , . . . . . . . , . . . . . . . . . . ' . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 19 Surface J:asing,prQtects. all.known. USDWs . . . . . . . . . . . . , . . . . . . . . . . . . . . .Yes. . . LikeJY.noJr.esh water.present.. Casing, set and .cemellted.to surface as. proposed. will protecLany po.ssible USDWs 20 .cMTv.oLa,dequ.ate.to ÇÌrcIJlate,oncondlJct.or.& SUJf.Cßg . . . . . . . . . . . .. ....... .Yes. . . . . . . . . . . . . . .. ,....... . . . . . ., .....,.. . . . . . . . . . . . . . . . . . . . . . . 21 .cMTv.ota.dequ.ate.totie-inJong$tringto.surfCS-9............ ............. N.o....... .Annulardisp.osalplalJned...... ....................................... 22 .CMTwill cover.all known productive borilon$. . . . . . . . . . . . . . . . .Yes. . . . . . . . . . . . . . . . . . . . . . .. ....,............... . . . . . . . . . . . . 23 .Casiog de.si.gns adequate f.or C.T, B .&permafr.osL . . . . . . . . . . . . . . . . .Yes . . . . . . . . . . . . . . . . . . . . . . ,. ...................................... 24 Adequate.tankªge.orre$elYe pit. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Yes. . . . . . . Rig is.e.quippedwitb steel pits. . No.rese.rv.e.pitplanne.d, although.cuttingsmay Þe st.or,ed .00 ice per.DE.C. . . . 25 Jfa.re-dr.iII,basa10-4.03foJaba.ndonmentbeeoapproved... _ .......... _...... NA ....... .permit..Cu,ttingsplªnnedto.be.haulecLLiq,uidwastestoapproved.anlJulus. ............... 26 Adequatew.elJbore.s.eparationproposed_ _,..... _ _.,........ _ _,........ _, .Yes. _. _ _. ,lIIearEtstwelLis 3 miles.away., ,.. ..... _ _....... . _.... ..... _".......,..... ...... 27 Jf.diverter rEtquirEtd, do.es it meetreguJa.tions. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . , . . . . . . . . . . . . . . . . . . . . . , . . . . . . . . , . . . . . . . 28 DrilJilJgfluid.programschemªtic.&,EtquipJisLadeq,uate.......... .......... .Yes."... .Mªxjmumexpected.f.ormation.pres.sure.11.9.EMW..MW.pJanoed.u,p.to12.5.. ......,.....,. 29 ßOPEs,.dothey meetreguJa.tion . . . . . . . .. ......,. . . . . . . , .. ....... .Yes. . . . . . . .. ...................,.....,..........,... ...... . . . . . , . . 30 ßOPE,pre.ss ratiog appropriate; tEtst to (put psig in.comments). . . . . , . . . . . . . . , , . . . . .Yes. . ., '. MAS~ based On sh.OE! br,eakd.owlJ 188.1 psi, ba.sed on BHI' 4785 psi.. PlaonedBOP.test pressure. 4000 psi.. . . . 31 .choke.manifold compJies w/APLRI'-53 (May 84). . . . . . . . . . . . . . . . . . . . . ' . . . . .Yes . . . . . . . . . , . . . . . . . . , . . . . .. ..........,................,.,........ ...... 32 WOJk will .oGCur. withouLoperation,sbutdown. . . . ' . . . . . . ., .........,....... .Yes. . . . . . . .. ........ . . . . . . . , . . . . . . . . , . . . . . . . . , . . . . . . . . . . . . . . . . . . . . . . . . . . 33 Js.pres.eoce.oJH2Sgas.prob.able.,........,.......................... N.o,...... .1:I2SisulJlikelysiocethewEtIUsnotplannjn.gtopEtnetratetheLisbume, Rig ha.s.sens.ors and alarms, ....... 34 MeçhanicªI.c.olJdjti.on .ot wells within AOR verified. (For.service well only) , . , . . . . . , . . . NA . . . . . . . . . . . . . . . . . . . , . . . . . . . . . , . . , . . . . . . , ' . . . . . . . . . . . . . . . . . . . . . . . . . . . , . . . 35 Per.mitcao be issu.ed wlo, hydr.ogen.s.ulfide meaSIJr.es, . . . . . ' . . . . . . . . . . . . . . . . .Yes . . . . . . . IIIQ H2S bas been Etncou.nteredilJ this,secti.oo in.offsEtt wells. .Rig will ha.ve sensors.. . . . . . . , 36 Data.prEtselJted on. potential .overpressure zones, . . . . . . , . . . . . . . . , , , . . . . . . . .Yes. . . . . . . SEtismic pore press!Jre.prEtdiction. reportJlJcJu.ded., ~ressure.pro.file,similar. to th.at in,3.offse.t wells; , . 37 .Seismicanalysis.oJ shaJlow gas.zolJes, . . . . . . . . . , . . . . . . . . , , . . , . .Yes. . . . . . . elevated pressurEt froJ1'1 -1000'-.2200; .normal pressIJr,e,220Q'-70QO~ theo elevatEtdJrom.7.00Q'-J"D, . . . , . . 38 SeabedcollditiOIJ$urvey.(ifoff-sh9re)...."........................... .NA...... ,2/4/04:.operatorsa.w.llo.evidence.ofshallow,gasin.3D.s.ei.smic.data, WeJlwiILbe.mudtogged.,......,. 39 .Co.ntactnam.e£PhoneJorweekly progress.reports [explorat.ory,only]. . . . . . . . . . . . . . . .Yes. . . . . . . JealJ-Francojs.l'rost..DriJling MalJa.ger, 9Q7~7.43-:097'0,. . . . . . . . . , . . . . . . . . , . . . . . . . . . . . . . . , , Geologic Commissioner: Date JJT~ Date: Engineering Commissioner: Public Commissioner Date <-I s /1-