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Home My WebLink About203-173 e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ;{ð.3- ~. 'J 3 Well History File Identifier D Two-sided 1111111111111111111 Production Scanning Stage 1 Page Count from Scanned File: 1'-f (CO"", does Incl"de)?'e' sheet) Page Count Matches Number in sca.nn~g PI. epa~ation: V YES BY: ~ Date: II if, oft; Stage 1 If NO in stage 1, page(s) discrepancies were found: Organizing (done) RESCAN ~olor Items: D Greyscale Items: DIGITAL DATA D Diskettes, No. D Other, No/Type: D Poor Quality Originals: D Other: NOTES: Date I J If/of;; Date 1/4-1 D0 º' X 30 = & () Date I J 4-10& BY: ~ (, lVIar!!l) Project Proofing BY: ~ Scanning Preparation BY: ~ BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: D Rescan Needed 1111111111111111111 OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) D Logs of various kinds: D Other:: /s/ mf 11111111111111 I11I1 /s/ rnp + 1<.3 = TOTAL PAGES '13 (Co"nt does not '~~"de co.., shlet) rnp 1111111111111111111 NO V11P /s/ YES NO /s/ 1111111111111111111 1111111111111111111 /s/ Quality Checked 11/1111111111111111 10/6/2005 Well History File Cover Page.doc • MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ri~ . F:~LaserFiche\CvrPgs_Inserts~Microfilm Marker.doc 203-173 . . Subject: 203-173 Date: Thu, 30 Oct 2003 10:36:39 -0900 From: tom _ maunder@admin.state.ak.us To: Jody J Colombie <jody_colombie@admin.state.ak.us> Jody, Enclosed is the proposed letter for Pelican Hills next well. On the original well, Pelican Hill gave approval to give the permit to Arlen. Could you please finalize?? Thanks Tom - ~1 Œj Name: 1 203-172.doc 203-172.doc Type: WINWORD File (application/msword) ! Encoding: base64 .J 1 of 1 10/30/200310:41 AM . mJ} !Æ~!Æ~ !Æ . AlfASKA. OIL AND 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 Mr. Al Gross Pelican Hill Oil and Gas Inc. 1401 N. El Camino Real, Suite 207 San Clemente, CA 92672 Mr. Arlen Ehm 2420 Foxhall Drive Anchorage, AK 99504 Re: Iliamna No.2 Pelican Hill Oil and Gas Inc. Permit No: 203-173 Surface Location: 1710' FNL, 187' FWL, Sec. 29, T9N, R14E, SM Bottomhole Location: 1710' FNL, 187' FWL, Sec. 29, T9N, R14E, SM Dear Messrs. Gross and Ehm: Enclosed is the approved application for permit to drill the above referenced exploration well. This permit to drill 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. On page 3 of the application, Pelican Hill requests waivers to 11 Commission requirements. Similar requests were evaluated for the Illiamna #1 (203-172) and were granted to drill that well. The approvals are valid for this well. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at 659-3607 (pager). Sincerely, ~ ~cL~ Randy ¡¿edrich Commissioner BY ORDER OF THE COMMISSION DATED thid.? day of October, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section . . /Æ/ ARLEN EHM Geological Consultant AAPG Certified Petroleum Geologist Certification #2503 2420 Foxhall Drive Anchorage, AK 99504 Phone: 907-333-8880 * Fax: 907-333-3454 E-mail: arlenehm@gci.net October 10, 2003 Ms. Sarah Palin, Chairman Alaska Oil and Gas Conservation Commission 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Drilling Permit Pelican Hill Oil and Gas Iliamna No.2 Dear Ms. Palin: Attached is an application for a drilling permit and a plan of engineering covering those operations. Also included is a Plan of Operations that was filed with the Division of Oil and Gas. For your information, we are also filing a nearly identical application for Iliamna No.1, which is within the same prospect area. Application for permits has also been made to other pertinent state, borough and federal agencIes. As all of the industry is aware, Governor Murkowski is in the process of streamlining the permitting process for oil and gas projects. The Governor recently asked Pelican Hill to keep him apprised of all correspondence to state agencies relative to the obtaining of permits. Therefore we are providing his office with a complete set of pertinent permit applications. Sincerely, ~~ Arlen Ehm Geological Consultant Cc: Governor Murkowski Al Gross, Pelican Hill Oil and Gas RECEIVED 1 0 Enc. & Gas Cons. Comcm;;swn Anchor<i¡¡c OR\G\NAL L . e ÅO(7,Ò 1 a. Type of work Drill X Redrill 0 Re-entry 0 Deepen 0 2. Name of Operator Pelican Hill Oil and Gas Inc. 3. Address 1401 N. EI Camino Real, Suite 207 San Clemente, CA 92672 4. Location of well at surface 187' FWL & 1710' FNL Sec.29 -T9N-R14W STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 1b. Type of well Exploratory X Stratigraphic Test 0 Development Oil 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 0 5. Datum Elevation (OF or KB) 10. Field and Pool 46.5 Feet 6. Property Designation ADL 388133-1 7. Unit or Property Name lIiamna 8. Well Number 2 9", ðAAfoximate spud date ~r5,2003 14. Number of acres in property None 11. Type Bond (see 20AAC25.025) Irrevocable letter of credit to be supplied At total depth Same 12. Distance to nearest property line 2,500' 2,640' 16. To be completed for deviated wells Kickoff depth feet Maximum hole angle 0 18. Casing program size Specifications Hole Casin Weight Grade Coupling g 13 3/8" 9 5/8" 51/Z' 13. Distance to nearest well Amount $200,000 15 Proposed depth (MD and TVD) Length 4,400 5,500 MD 5,500 TVD 17. Anticipated pressure (see 20 AAC 25.035 (e)(2) Maximum Surface )Þ18"'PS¡g. At total depth (TVD) 2574 psig Setting Depth ~O ~'1. f.-9-~fl4 Top Bottom Quantity of cement TVD MD TVD MD 143/4" 121/4" 77/8" 54.40# 32.30# 15.5 R-3 H-40 JSS Buttress Buttress Buttress 60' SSO' 5,500' 0' 0' 0' 0' 80' 80' 18sx=20CF 0' 550' 550' 192 sxs = 283 CF 0' 5,500' 5,500' TBD Based on top of Shows. Plan is for 191 sxs Lead + 149 sxs Tail = 347 CF Lead + 173 CF Tail 0' 5,500' 5,500' None 5-1/2" 27/8" 6.50# K-55 EUE 8Rd 5,500' 0' Csg 19, To be completed for Redrill. Re-entry and Deepen Operations Present well condition summary (' '-'" 1 0 20. Attachments: Filing Fee X Property Plat X X :'\1 BOP Sketch X Diverter Sketch X Àn(mr:i"um-~ Program W/Exceptions Drilling Fluid Program X Time vs Depth Plot X 20MC25.050 Requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~'? ~ Title: Geological Consultant Date /1)- / IJ -0 J Commission Use Only Permit Number 7:< I API Number I Approva] dJ~~ ""'J.. I S.ee cover.lette. r 203.... 170 50- /33- ~5ZS ~óO /d¡.!i?- '!JJ for otherrequirements Conditions of approval Samples requi.!J;d 0 Yes .¥No Mud log required )(Y '*'0 No -it' Þ~.ft!--. .fr~.'f« el-F.LfrtY1. \/~. C-Ý.,-il¡ Hydrogen Sulfide measures 0 Yes ~No Directional Survey required þ!1 Yesfm No .';(()f. I.t\L'."~~~:/,'::'tJ~1~!~:/.: ¡$Ä Required working pressure for BOPE 02M 03M 05M 010M 015M :f' ,.-J Other: ~oaO ~\ 'bO\=> ~..ð\- _ / by order of /~ ~ I '\ Approved by f f.. ...A ~ '- ~ Commissioner the commission Date / t/ 'J' ~ '¿j.....) / '" Su it in riplicate ORtG'~"LAi" - .., ~ ., ~ 19 20 R R 15 14 W W 1 1710' ILlAMNA 2 ~ (SET 5/8" REBAR) 187'- 30 29 SCALE: 1" = 2000' 25 36 31 32 Units:U.S. Survey Feet Horizontal Datum:NAD 27 Coordinate System:State Plane; Zone 4 Vertical Datum:NAVD 88 Horizontal locations are based on the NGS published coordinates for KUST AT AN RESET of (N2459539.34, E186278.03) Elevations were generated using RINEX data from CORS Stations TLKA (Talkeetna CORS ARP) and KEN1(Niki USCG B); ELEVATIONS ARE +/- 5' SECTION LINES ARE DRAWN USING PROTRACTED COORDINATES. R 15 W R 14 W T9N T8N Well Name Northing Easting Elev ILlAMNA 2 2505045.97 176985.35 46.53 6 , F. Robert 1- 1]_- ~ ffi~~rnœo LOCA TION OF PELICAN HILL OIL & GAS INC. WELL LOCATION FOR ILlAMNA 2 SEC. 29, T 9 N, R 14 W, S.M., AK "'~ ENGINEERS AND LAND SURVEYORS PREPARED FOR: PELICAN HILL OIL AND GAS INC. DRAWN BY: JZW CHECKED BY: CBS JOB NUMBER: 2003-510 801 WEST FIREWEED LANE SUITE 201 ANCHORAGE. ALASKA 99503-1801 CNE (907)-274-5257 SCALE: 1" = 2000' j ./ ". . ~ ~ r í 9 20 R R 15 14 W W t 1710' ILlAMNA 2 1-_1 (SET 5/8" REBAR) 187'- 30 29 SCALE: 1" = 2000' 25 36 3í 32 Well Name Northing Easting Elev ILlAMNA 2 2504813.31 1317008.09 46.53 R 15 W R 14 W T9N TaN Units:U.S. Survey Feet Horizontal Datum:NAD 83 Coordinate System:State Plane; Zone 4 Vertical Datum:NAVD 88 Horizontal locations are based on the NGS published coordinates for KUSTATAN RESET of (N2459304.37, E1326298.47) Elevations were generated using RINEX data from CORS Stations TLKA (Talkeetna CORS ARP) and KEN1{Niki USCG S); ELEVATIONS ARE +/- 5' SECTION LINES ARE DRAWN USING PROTRACTED COORDINAT 6 r F. Robert 1- l]~~ ~ ff]g)g)rnœo LOCA TION OF PELICAN HILL OIL & GAS INC. WELL LOCATION FOR ILlAMNA 2 SEC. 29, T 9 N, R 14 W, S.M., AK ""' ENGINEERS AND LAND SURVEYORS PREPARED FOR: PELICAN HILL OIL AND GAS INC. DRAWN BY: JZW CHECKED BY: CBS JOB NUMBER: 2003-510 1" = 2000' SCALE: 801 WEST FIREWEED LANE SUITE 201 ANCHORAGE. ALASKA 99503-1801 \. PHONE (907)-274-5257 .) 1/ / ~o t::::i ADl398131 ADl 399133~1 T9N TeN o 2000 4000 ¡ I na Prospect Formline Time Structure on Tyonek Fm Pelican Hill & Gas Company 2003 D /.:V: Time contours (see) Faults Pelican Hill O&G leases ( Pelican Hill Oil &Gas Company Proposed Well locations for liiam na #1 & #2 October 2, 2003 \... e e PELICAN HILL OIL AND GAS, INC. DRILLING PROCEDURE ILIAMNA NO.1 & NO.2 By Jim Mosley, Well Digger Inc. Drilling Consultant for Arlen Ehm - Geological Consultant Pelican Hill Oil and Gas, Inc. and Truman Hicks -Drilling Supervisor Pelican Hill Oil and Gas, Inc. ILIAMNA DRILLING PROCEDURE REV Pelican Hill Oil and Gas, Inc. Page 1 10/1 0/03 e e TABLE OF CONTENTS AOGCC WAIVERS REQUESTED IN TIllS PERMIT TO DRILL........................................................... 3 RIG PREPARATIONS AND PREDRILL ACTIVITIES........................................................................... 4 "PRE SPUD AND INITIAL RIG UP OPERATIONS..................................................................................5 SPUD IN, DRILL 14-314" HOLE TO 80 FEET, RUN AND CEMENT 13-3/8" ........................................ 6 DRILL 12-114" HOLE TO 550 FEET, RUN AND CEMENT 9-5/8" CASING.......................................... 7 NIPPLE UP AND TEST BOPE AND .ACCUMULATOR........................................................................ 8 BOPE SCHEMATIC FOR BOPE TEST REPORT ................................................................................. 10 DRILL 7-7/8" HOLE TO 1D AND SET 5-1/2" CASING WITH CASING DRILLING TOOLS ............. 13 NIPPLE UP TUBING SPOOL, RUN LOGS AND TUBING WITH PRODUCTION PACKER.............. 14 ATTAClIMENTS TO DRilLING PROCEDURE........... ......... ................ ............ .................... ...... ........ 15 MUD PROGRAM........ ................ .................. ... ...... .... ................. ......... ........ ... ........ ................ .............. 16 PROPOSED FRACTURE GRADIENT AND MUD WEIGHT CHART .................................................29 CASING PROGRAM, CASING SAFETY FACTORS AND BOPE RATINGS ...................................... 30 BJ SERVICES CEMENT PROGRAM ................................................................................................... 31 LOCATION LAYOUT FOOTPRINT DRAWING ................................................................................. 43 RIG LAYOUT WITH DIVERTER LINE IN PLACE .............................................................................44 DIVERTER ST ACKUP DRAWING ........ ..................... ......................... ....... ........................ ................. 45 DIVERTER CLEARANCE DRAWING SHOWING KNIFE VALVE LOCATION................................ 46 BOP EQUIPMENT STACKUP WITH SURFACE WELLHEAD AND SPACER SPooL...................... 47 BOP STACKUP WITH PRODUCTION CASING WELLHEAD AND TUBING SPOOL ...................... 50 CHOKE MANIFOLD ............................................................................................................................ 51 ACCUMULATOR VOLUME REQUIREMENTS AND BELL NIPPLE DESIGN ................................. 55 BELL NIPPLE DRAWING FOR USE ON ALL THREE NIPPLE UPS.................................................. 52 SWAB KICK TOLERANCE CHART ..................................... ............. ....... ..... ........ .............................. 53 PRESSURE KICK TOLERANCE CHART ............................................................................................ 55 PROPOSED WELLBORE SCHEMATIC .............................................................................................. 57 PROPOSED DAYS VERSUS DEPTH CURVE ..................................................................................... 58 PROPOSED COMPLETION SCHEMATIC...... ........... ......... ........... ... .... .... ................... ... .......... ...... ..... 60 PROPOSED XMAS TREE AND WELLHEAD EQUIPMENT SPECIFICS ........................................... 61 ILIAMNA DRILLING PROCEDURE REV 100CT.doc Pelican Hill Oil and Gas, Inc. Page 2 10/10/03 e e AOGCC WAIVERS REQUESTED IN THIS PERMIT TO DRILL 1. Use of a diverter line sizing of 12" which is W' smaller that the size of the surface hole bit. 2. Use of threaded outlets on choke and kill lines. The maximum anticipated sUIface pressure is expected to be less than 2000 psi and a waiver rrom the rigid lines requirements is requested. 3. Use of existing BOP control line hoses is requested. These hoses are not armored like coflexip. The accumulator control lines will be run in a tray and wrapped with fire protection insulation across the intervals in the substructure where the lines are not run in protective trays. 4. Use of crossovers on the 3-1/2" TIW and mop is requested in lieu of full opening valves. The Planned Casing Drilling Operation is not conducive to utilizing a 5-1/2" TIW or mop. Therefore, approval of the use of3-1/2" drill pipe size equipment is requested. 5. Drilling of the surface hole to a depth of 5 50 feet without the use of a trip tank is requested for the following reasons. The interval will be drilled with a top drive and the space limitations on location are such that the diverter line occupies the space required for the existing trip tank and choke manifold. The trip tank will be set once the diverter operation is finished and the diverter line nipp1ed down. 6. A waiver rrom the requirement of using manned mud logging operations and of collecting, washing and retaining a set of well samples is requested. The well density in the general area is such that no significant additional knowledge will be gained by having personnel on location to catch samples and to mud log. Remote mud logging will be conducted via electronic monitoring and this log will be provided to the AOGCC. 7. A waiver rrom the requirement for wellbore surveys while drilling is requested. Casing drilling operations do not trip the pipe or BHA while drilling and have produced straighter holes than those with normal drilling assemblies. Directional surveys are normally taken with either wireline or MWD. Casing drilling operation are planned and these operations have produced straighter holes than those with standard drilling assemblies. This well is planned as a relatively shallow straight hole and will be directionally surveyed after completion. 8. A waiver to stop the leak off test of the surface shoe at 14.0 ppg EQ is requested. The well plan anticipates using 10.0 ppg mud for the interval from the surface casing shoe to total depth. The anticipated rracture gradient at 550 feet is about 14.0 ppg EQ. The operator does not see any benefit to breaking down the shoe during leak off testing. 9. A waiver rrom the requirement to maintain H2S protective equipment on site is requested. This well is planned as a shallow sweet gas test of previously identified reservoirs that have not encountered H2S in nearby wells. Drill stem testing is not planned and, consequently, there will not be any H2S encountered. The operator will maintain gas detection equipment in strategic areas so that any gas or H2S will be detected and the appropriate response can be made safely. 10. A waiver of the distance requirements for the spacing of equipment rrom well bore is requested. This compact rig and its support equipment make a very small footprint, which requires that a lot of support equipment be placed within short distances rrom the well bore. All ignition sources, except the drawworks engine, are within their own buildings or are at, a minimum, separated by other building housed rig components. For example, the accumulator is about 20 feet rrom the wellbore, but separated from it by a water tank: and the accumulator house. NOTE: That this request does not include the diverter line, which will be as per the regulations. 11. The elimination of open hole logs is requested. Well density in the area make the surface hole log unnecessary. Given the Casing Drilling operations do not normally provide for tripping, open hole electric line logs are not obtained. In lieu of open hole logs, Pelican is planning on running a cased hole log to identify gas bearing intervals. A waiver rrom the logging requirements is requested. ILIAMNA DRILLING PROCEDURE REV IOOCT.doc Pelican Hill Oil and Gas, Inc. Page 3 10/10/03 e e RIG PREPARATIONS AND PREDRILL ACTIVITIES 1. Finish building rig pits, installing electrical lines, piping, and instrumentation equipment. 2. Install and fit test top drive casing drilling system. Dismantle it and prepare top drive equipment for shipping. 3. Install accumulator in trailer with air compressor and storage units. 4. Preinstall pit monitoring and gas detection equipment. 5. Prefabricate and procure wellheads, bell nipple, BOPE stack, hydril, accumulator lines, spacer spools, diverter lines, and drilling spool. 6. Procure water tank and cuttings holding tanks. Ensure that water tank has steam lines installed. 7. Obtain and prepare to ship sufficient matting boards and matting to double layer under rig and to cover the location and roads as per the land use agreement and DEC approval. 8. Contract for trucking to haul and deploy rig ftom yard to North Star Terminal. Rig is 21 loads plus top drive and composite matting boards. 9. Contract for a barge company to move rig and associated equipment to Trading Bay Production Facility barge landing.. 10. Contract for surveyors to survey and stake location and provide plat for the location. 11. Share the costs of drilling a water well with UNOCAL at the TBPF. 12. Contract for a vacuum truck at site. A super sucker vacuum is preferred so that cuttings movement can be handled with the vacuum, truck if necessary. 13. Arrange for Bulk Cement to be delivered to the site. Arrange for additional barge shipments as needed. Cementing equipment should include at a minimum: two bulk silos for storage of cement at the TBF; one bulk truck for use to move per job cement volumes to the well site; one bulk hopper for the well site; and a cement mixing plant and pump for mixing and displacing cement into the casings and wellbore. The cement jobs are expected to be pumped as two stage jobs with one stage of bulk in a bulk tank and the other in the bulk truck. Sufficient heated water on location will be required to mix each cement job. See cement plan for details on bulk volumes, mix water requirements, chemical additives, etc. 14. Prepare Tubular Products and Casings for Shipment to West Side. 15. Move sufficient fuel and fuel storage tank: to West Side. Rig Tank: is 10,000 gals. Ensure that at least 20,000 gals are on hand. 16. Move steam generator to the Trading Bay facility and have same prepared in a standby mode for moving to rig site and temporary use during cold weather and prior to cement jobs. 17. Function test accumulator and BOP's prior to moving to West side. Ensure that accumulator has environmentally ftiendly hydraulic fluid. 18. Check all radiators and ensure that all radiators have been flushed and filled with environmentally ftiendly antifteeze suitable for minus 30 degrees. 19. Verify that all drilling assemblies and crossovers have been inspected and will screw together. 20. Ensure that a back up set of tools are available for each drilling assembly. 21. Ensure that a TIW valve and an mop are available for the 3-1/2" Drill pipe and for the 5-1/2" Casing. A crossover on each ftom drill pipe to casing thread is acceptable provided that the valves will test. 22. Prepare diverter lines with RF 150 flanges in advance and have at least two 25 foot pieces and one 5 foot piece with flanges preinstalled. Note: one 25 foot piece can have flanges on one end only. 23. Ensure that 2 foot sub and ramp are ready to be transported to West Side. 24. Ensure that sufficient mud products are delivered to the West Side. 25. Ensure that bell nipple has been fabricated to match the attached drawings. ILIAMNA DRILLING PROCEDURE REV 100CT.doc Pelican Hill Oil and Gas, Inc. Page 4 10/10/03 e e PRESPUD AND INITIAL RIG UP OPERATIONS 1. Install interlocking rig mats on location and roadway. See location drawing and roadway route drawings for details on areas to be covered with interlocking mats. 2. Install impermeable barrier of pit liner material over roadway and location. This will be placed over the matting. 3. Place 6" Board mats where substructure is to be placed. 4. Dig and install 7-foot diameter cellar and place mats as needed to allow access to the cellar. 5. Set 2-foot substructure base and back rig in. Set remaining substructure. 6. Set mud tanks and begin hooking up lines and instrumentation. 7. Set mud pumps, and generators and hook up all lines and valves. 8. Set water tank and place doghouse on top. Plumb water tank 9. Place accumulator building. Fill pits and solids control equipment with water. Leak check all fittings, hoses valves, etc. Set trip tank as per location rig up drawing. NOTE: After rigging down the diverter lines the trip tank will be turned around so that the choke manifold and gas buster can be rigged up. 10. Set gas buster and hook it up to the rig pits. Note: the gas buster will not be used during the first 500 feet of drilling. 11. Layout diverter lines ready to bolt together and anchor line. 12. Put 13-5/8" wellhead, diverter spool and hydril into end compartment of substructure. 13. Set catwalk and V-door slide. 14. Set remaining ancillary equipment, doghouse mud logging shack, tool sheds, etc. 15. Install containment berm around all rig components. 16. Begin filling water tanks, mud pits, and fuel tanks. 17. Prepare to raise mast 18. Fire up generators, heaters, steam generator, and air compressors. 19. Fire up rig engines and mud pumps. 20. Layout guy wires and check all of the mast for verification that it is ready to raise. 21. Raise mast ITom horizontal to vertical. 22. Telescope up the upper portion of the mast and pin it. Secure guy wires and anchors. 23. Set Tesco top drive power unit and hydraulic lines. 24. Begin mixing spud mud. 25. Install the cellar jet pump and plumb it to put returns across shaker. 26. Set top drive rails on catwalk and begin installing it in mast. 27. Set top drive unit on catwalk and pick it up with blocks. Install TBAR stiffener to top drive and hook up Kelly hose and hydraulic hoses. 28. Set 6" drill collars and BRA on catwalk. Pick up 14-3/4" drilling assembly and prepare to drill to 80 feet. 29. Set pipe racks and cuttings tank. Place two joints of 13-3/8" casing on pipe racks. 30. Place sufficient drill pipe on pipe racks to drill to 550 feet. Place 12-1/4" tools on end of catwalk ready to move to the rig floor after drilling the 14-3/4" hole. 31. Rig up BJ cementing unit and place bulk hopper and lines such that the two cement jobs can be done ITom one rig up. The 13-3/8" cement job is a very small job and can be considered a warm up to the 9-5/8" job. 32. Lay cementing lines to the catwalk and place cement standpipe against substructure. Chain standpipe in place and lay chicksan lines to BJ unit. 33. Rig up gas detectors and verify that PVT system is working. Verify that remote mud logging unit is functional. ILIAMNA DRILLING PROCEDURE REV 100CT.doc Pelican Hill Oil and Gas, Inc. Page 5 10/10/03 e e 34. Install Koomey hoses in fire protection tray and lay same to edge of substructure. Inspect rig location for completeness of rig up and for adequate environmental protection and spill containment. Place impermeable barrier and berms as needed to contain location runoff Berm a diverter pit with barrier under the end of the diverter line. See attached location layout drawing for placement of equipment and for any revisions needed. 35. Notify AOGeC of intent to spud. SPUD IN, DRILL 14-3/4" HOLE TO 80 FEET, RUN AND CEMENT 13-3/8" r 11. Ensure that bit and drilling assembly are in the center of the cellar. Wash the first few feet and then drill 14-314" hole to 80 feet taking returns to the cellar and pumping mud and cuttings trom cellar to shaker via the cellar pump. Use one pump and low flow rates to avoid washing out trom under the rig. See hydraulics program, bit program and mud program for details. Circulate hole clean and pull out of hole keeping hole full. Lay down 14-314" bit and stand back 6" drill collars if possible, otherwise lay down drill collars. Pick up two joints of 13-3/8", 54.5#, K-55, BTC casing and run in hole with same using air hoist to run the casing. Set casing on bottom and if necessary wash to bottom. Rig up BJ fast lock head and prepare to cement 13-3/8" casing. Mix and pump cement job as per the BJ cementing program. Hold pressure on the cement for a minimum of 6 hours. Release pressure and slack off the casing. Remove fastlock cement head and prepare to cut casing. Rough cut 13-3/8" casing and lay down stub. Final cut 13-3/8" casing as per diverter drawing and space out requirements. Install slip lock 13-5/8" 5M wellhead and diverter tee as per diverter drawing. Install knife valve and hook up diverter lines to ensure that the diverter lines run downhill. Install control lines to diverter and knife valve. Install bell nipple and fill hole with water up to the diverter tee onlv. Install flowline and flosho. " Pick up drill collars and run same in hole. Function test diverter bag and knife valve with drill collars in hole. This will prevent unnecessary damage to the hydril element. Ensure that accumulator closing pressure for the diverter bag is at regulated to be at least 1000 psi but not more than 1500 psi. Open diverter and knife valve. Ensure that diverter lines are not holding fluid and cannot fteeze up. Pick up 12-1/4" drilling assembly as 8-1/2" Bit and 12-1/4" RWD or underreamer as per bit program. c.o~c* ~G~ Ç-0'- ~.,\-~<;<s 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. ILIAMNA DRILLING PROCEDURE REV 100CT.doc Pelican Hill Oil and Gas, Inc. Page 6 10/10/03 e e DRILL 12-1/4" HOLE TO 550 FEET, RUN AND CEMENT 9-5/8" CASING r -"-'''''e,. 1. Run in hole to top of cement with 6" drill collars. Pretreat mud for cement contamination. Wash and drill to bottom. Function test mop and TIW valves. Ensure that both are on the rig floor and that an operating handle is at hand. Check all PVT flowsho equipment to ensure it is in working order. Verify that gas detectors are all functioning correctly. Lay sufficient drill collars on catwalk as needed to provide at least 15000 pounds of weight to the bit. Dri1112-l/4" Hole to 550 feet as per bit, mud, and hydraulics programs. Catch cuttings in cuttings tank and de-water same with trash pump as needed. Drill to 550' reaming each connection. NOTE: Drill hole to fit casing strap based on depth of underreamer. Circulate bottoms up and pull out of hole. If hole pulls slick, then rig up to run 9-5/8" casing. If hole had tight pulls, then make wiper trip, circulate out again, and pull out of hole prior to attempting to run casing. Ensure that high viscosity mud is left in hole prior to pulling out of hole for casing. Monitor hole fill-up and maintain hole full while tripping pipe. Lay Down RWD or Underreamer and stand back remaining BHA and drill pipe. NOTE: Standing back is not an option. The drilling assembly will be laid down prior to rigging up to run casing. Rig up to run casing. with top drive. Run and cement 9-5/8",32.3#, K-55 buttress casing as per mud, and cement programs. Ensure that float shoe has receptacle for non-rotating composite cementing plug. Use ofPDC drillable cement plug with non-rotating feature is preferred. Five centralizers, one each on the first five joints are recommended. Run casing to bottom, washing as necessary to place casing shoe on bottom. Pick up casing one foot above bottom and hold in place during cement job. Bump plug, hold pressure on 9-5/8" casing for 30 minutes and record same on chart recorder as casing pressure test. Release pressure. Confirm float is holding. Place any excess cement in cuttings tanks and retard same. Hold casing in place for a minimum of eight hours. The 9-5/8" wellhead will be welded on after cutting off the 13-5/8" head. SEE BOPE drawings of stack up for correct heights to cut off casmgs. Cot--~l'.\: ~OGCC ~ rßO\' \cec. \ Wi tç"'-Q s. s .. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. HOLE SECTION NOTES NOTE: If well control situation arises on surface hole, driller will operate diverter valve, close Hydril and shut down mud pumps and engines. Crew will muster at pre-designated area. If lost circulation occurs, establish loss rate at full drilling circulation rate. Contact drilling engineer and mud company representative to discuss options. a) Begin drilling with water base-mud starting at 9.5 ppg and allow the mud weight to rise to 10.0 ppg. Maintain mud weight by controlling solids with mud cleaner operation. The cuttings will be stored on site in a steel tank. Use vacuum truck and/or 966 loader to move cuttings as needed. b) NOTE: Utilize all fluid and waste transfer tracking documents as per MI Drilling Fluids ILIAMNA DRILLING PROCEDURE REV IOOCT.doc Pelican Hill Oil and Gas, Inc. Page 7 10/10/03 e e Recommended Mud Properties for Surface Hole: Density: 9.5-10.5 ppg Viscosity 44-100 sec/qt PV 12-16 cps yP 15-40 lb/lOOft2 Gels 15-30 Fluid Loss NC to 6-14 cc API PH 9.0-9.5 Contingency usage of lost circulation material on site includes: Seepage losses- Add 5-10 ppb graded calcium Carbonate Moderate Losses- Mix 10-30 ppb of Seal Fine & Medium while drilling and/or spot pills across loss zones. c) No known shallow gas zones exist; however, swabbing potential exists on all trips. Because of the considerable length of production of the nearby Trading Bay field, there is always a possibility of some shallow gas accumulations occurring. Continuously fill the hole on all trips while the diverter is in use. Discuss tripping procedures with all personnel. Do not POOH at high speeds. Use trip tank: sheets and continuously fill hole on all trips. Check for swabbing on each stand out of hole. If swabbing appears to be an issue, then use top drive to pump out of hole. d) Gas/H2S detection and monitoring drilling parameters will begin rrom the surface. e) Rig crews will participate in a pit drill or trip drill each tour. t) Accurately monitor trip tank and fill out trip sheets. g) Visually monitor hole at all times on trips. DO NOT USE STRIPPING RUBBER BELOW THE ROTARY TABLE. NIPPLE UP AND TEST BOPE AND ACCUMULATOR 1. The removal of the 9-5/8" casing and nipple down of the diverter will be done similar to the original stack up except that it will be necessary to cut the 9-5/8" several times to enable removal of the diverter pieces. Slack off on 9-5/8" casing and confirm that it will stay put. Nipple down the bell nipple and pick it up. Cut 9-5/8" right on top ofhydril. 2. Lay down cut piece and bell nipple. Nipple down rrom 13-5/8" wellhead and rough cut 9-5/8". Lay down cut piece and set back down with diverter. Nipple down and pick up Hydril. Set Hydril in sub. Nipple down diverter tee with 16" spacer spool and knife valve. Cut off 13-5/8" wellhead and send it to ABB Vetco for stub removal and redressing for next well. 3. Final Cut 13-3/8" casing as per BOP stack up drawing requirements for space out. Final cut and prepare the 9-5/8" casing top for welding on surface casing wellhead. See drawing for details. 4. Weld on II" 3M by 9-5/8" SOW wellhead and test void to 500 psi. Head should be preheated prior to welding onto 9-5/8" casing. 5. Ensure wellhead tests prior to nippling up spacer spool and BOPE. 6. Nipple up spacer spool, drilling spool, rams with 5-1/2" pipe rams installed in upper cavity and blinds in lower cavity, Hydril and bell nipple. 7. Install flowline and sensors. Hook up accumulator lines, choke and kill valves and lines. 8. Hook up gas buster and choke manifold. 9. Prepare to test preventers and accumulator. 10. Run and set test plug in 11" 3M wellhead. 11. Fill stack with water and verify system holds water. 12. Run test joint with TIW valve on top. Screw in with top drive and prepare to test. ILIAMNA DRILLING PROCEDURE REV 100CT.doc Pelican Hill Oil and Gas, Inc. Page 8 10/10/03 e e 13. Rig up test pump and chart recorder to record BOPE tests. Fill out BOPE test report and fax same with daily drill report. 14. Record and test BOPE as per the attached BOPE test sheet. Tests 1 through 4 test pipe rams, entire choke manifold, kill line, kill line valves, top drive, Kelly hose, and standpipe. Test 5 and 6 test blind rams and choke line valves. Test 7 tests Hydril. 15. Recharge accumulator and turn off power to all the accumulator pumps. Turn off air supply to air pump. Prepare to test accumulator. 16. Close and open Hydril, record pressure and closing time. Close and open blind rams. Record pressure and closing time. Close and open pipe rams. Record pressure and closing time. Close and open HCR valve. Record pressure and closing time. Record final accumulator pressure and verify that at least 1200 psi remains in the system. If the pressure is below 1200 psi, then each of the nitrogen bottles must be checked for correct precharge. 17 . VerifY that accumulator lines and control hoses are :£Tee of leaks, properly placed in the fire protection trays, and that the control hoses in the cellar area are adequately wrapped with fire protection insulation. 18. Line up choke manifold and kill line valves as follows. TIW and mop on rig floor, insidekillline valve closed, outside kill line valve open, inside choke line valve open, HCR closed, and choke manifold lined up to gas buster through the hydraulic choke with valves 1, 5, 7, and 8 open. All of the remaining choke manifold valves are to be closed. 19. Line up standpipe and Kelly valves as needed to begin next hole section. 20. Pull test plug and verify that mud is conditioned for cement contamination. 21. Pick up 7-7/8" drilling tools and crossover to 5-1/2" casing drilling string. ILIAMNA DRILLING PROCEDURE REV 100CT.docoPelican Hill Oil and Gas, Inc. Page 9 10/10/03 DOPE SCHEMATIC FOR DOPE TEST REPORT n A ...... A ~ A A v w nJAMNA DRILLING PROCEDURE REV lOOCT.doc n.....1.:................ TT':ll 1\':1 .-............3 r'......... T-..-.__ n......"'""..... 1{) 11\/1 A/A"" r1 10/10/03 lOOCT.doc Page 11 ILIAlvINA DRILLING PROCEDURE REV Pelican Hill Oil and Gas, Inc. e e DOPE TEST SEQUENCE SHOWING VALVE POSITIONS & REQUIRED TEST PRESSURES TEST # from Fill UP fÌ'om Test Joint with Top Drive #1 ITom Test Joint with Top Drive #2 ITom Test Joint with Top Drive #3 from Test Joint and NO Top Drive #4 from Test Joint #5 from Stand Pipe through Kill Line #6 from Stand Pipe through Kill Line Valves Valves Open Closed All None 1,2,3, 11, and Stand pIpe 4,8, 9, 10, and Top Drive IBOP 4,5,6, 10, and TIW TEST PLUG AND OR TEST JOINT Test Plug and Test Joint with Top Drive Test Plug and Test Joint with Top Drive Test Plug and Test Joint with Top Drive T est Plug and Test Joint Test Plug and Test Joint Test Plug T est Plug Test Plug and Test Joint Preventer Low High Objective of Test Closed Test Test Psi Psi Annular Leak Leak: Function and Fill System Check Check with Water. Pump through Gas Buster, and Kill Lines Pipe Rams 250 pSI Pipe Rams 250 pSI Pipe Rams 250 pSI Pipe Rams 250 pSI Blind Rams 250 pSI 4,5,6,7 ,8,9,10 , 12, 13, and TIW 1,2,3,5 ,6,7,11 ,12, 13, TIW and Stand Pipe J.,2,3,8 ,9,11, 12, and 13 1,2,3,4 7, and ,5,6,8, TIW 9, 1,2,3,4 13 ,5,6,7, 8,9, 10, 11, and 12 1,2,3,4 12 ,5,6,7, 8,9,10, 11, and 13 # 7 From 1,2,3,4 12 Test Joint ,5,6,7, 8,9, 11, and 13 NOTE:A 5-1/2" TEST JOINT WILL BE REQUIRED TO PERFORM THE ABOVE TESTS. USE OF A SHORT CROSSOVER TO THE TEST PLUG THREAD IS POSSIBLE PROVIDED THE LENGTH DOES NOT PUT THE CROSSOVER IN THE PIPE RAM. ILIAMNA DRILLING PROCEDURE REV lOOCT.doc Pelican Hill Oil and Gas, Inc. Page 12 Blind Rams 250 pSI Hydril 250 pSI 3000 pSI 3000 pSI 3000 pSI 3000 pSI 3000 pSI 3000 pSI 1500 pSI Shell Test of System, Outer valves, Stand Pipe, Kelly Hose, and Pipe Rams using Test Joint and standpipe Test inner Kill line Valve, Manifold Cross Isolation Valve, both manual and hydraulic Chokes, and standpipe Test Kill line inside Valve, Choke Manifold inside valves, Test Joint, and TIW Choke Manifold Isolation Valve Kill Line, Standpipe Valve, and HCR Valve Inside Choke Line Valve, Standpipe Valve and Kill Line Hydril, Shell Test of Stack, and Inside Choke Line Valve 10/10/03 e e DRILL 7-7/8" HOLE TO TD AND SET 5-1/2" CASING WITH CASING DRILLING TOOLS 1. Run in hole with 7-7/8" drilling tools picking up 5-1/2" 15.5#, K-55, buttress casing with torque rings installed in each joint. ------. 2. Cãfefully tag up on top of cement expected at 510 feet. 3. Begin drilling cement and plug with 7-7/8" PDC drilling assembly as per bit, mud, and hydraulics programs. 4. Drill from 550 feet to 575 feet and circulate out cuttings and cement contaminated mud. Condition hole for leak: off test. 5. Pull any casing collar out ofBOPE stack, close rams, and test casing shoe to an equivalent of 14.0 ppg or leak:off, whichever is lower. It is anticipated that the shoe will hold the 14.0 ppg EQ as a casing shoe integrity test. If shoe leaks off, contact drilling engineer for further recommendations. Ifleakoffis less than 13.0 ppg EQ, then a squeeze job will most likely be necessary. Contact mud company and cement company for further advice. 6. Ifleakofftest results are satisfactory, then drill ahead as per bit, mud, and hydraulics programs. Drill to 5500 feet while maintaining mud weight as per the program and monitoring gas via the unmanned equipment. Fax reports and mud log to Anchorage daily. 7. Report all gas shows to Arlen Ehm immediately. A gas show is any show that has double the background gas units. NOTE: Kick tolerance decreases dramatically as the well is drilled deeper. Maintain mud weight as per plan and if indicated increase mud weight as needed to keep background gas below 100 units. Expect numerous coal beds with gassy mud log results. Maintain weight on bit and rotary as per bit recommendation from Tesco. 8. Upon reaching total depth, circulate out for two bottoms ups and until well appears quiet. Rig up to cement 5-112 Casing as per cement program. Ensure that sufficient heated water is available for the cement job, that the cement and field water samples have been lab tested and that the casing cementing tools are ready for the job. Casing slips should be dressed to be dropped from the rig floor after the cement job. Have tubing spool ready to be installed once the 5-1/2" is set. 9. Rig up BJ and cement 5-1í2" casing as per cement plan. Bump plug and hold pressure on plug for 5 minutes. Release pressure and rig down BJ. Drain stack and drop slips on 5-112" casing. Ensure that 5-1/2" is landed with weight set slips. Set the entire weight ofthe 5-1/2" on the casing slips. 10. Cut 5-1/2" casing just above the bell nipple and lay down cut piece. Pick up bell nipple and recut 5-1/2" just above the Hydril. Remove cut piece, remove bell nipple and pick up BOPE rams and spacer spool. Rough cut 5-112" casing and lay down cut piece. Nipple down Hydril, rams, drilling spool and spacer spool. Install packoff on 5-1/2" casing slips. ILIAMNA DRILLING PROCEDURE REV 100CT.doc Pelican Hill Oil and Gas, Inc. Page 13 10/10/03 e e NIPPLE UP TUBING SPOOL, RUN LOGS AND TUBING WIm PRODUCTION PACKER 1. Install tubing head and drilling spool. Nipple up drilling rams and Hydril. Nipple up bell nipple. 2. Run test plug and change rams to 2-7/8". Test all BOPE rams, Hydril and all breaks in the system to AOGCC specs and as per BOPE test procedure attached herein. A 2-7/8" test joint and a 7- 1/16" test plug are required. Crossovers ftom the 3-1/2" IF TIW and mop are required to crossover to the tubing thread for both the TIW and the mop. 3. Rig up wireline and run pulsed neutron log ftom PBTD (TOC) to 500 feet above uppermost show. Top oflogged interval is expected to be 2500 feet. Continue running Gamma Ray and CCL log to the surface. 4. Prepare to run 2-7/8" tubing and packer. 5. The completion procedure interval details will be determined after logging and will be based on results ftom the pulsed neutron log. 6. For the purpose of this permit, the completion procedure will be generic and should only formalize the prospective intervals and perforation depths after logging. 7. Pick up TCP assembly loaded with 6 SPF DP charges to perforate as indicated by logging results and Rill on 2-7/8" tubing with packer and "X" nipple as per completion program recommendation. 8. Tubing assembly should include TCP Guns with bar drop firing head, auto drop sub, perforated sub, "X" nipple below packer, two joints of tubing, packer with millout extension, one joint of tubing, "X" nipple, and tubing to the surface. A chemical injection sub should be run at a depth of 1000 feet with a 3/8" control line to the surface so that methanol can be pumped into the well for fteeze protection during winter time production operations. The tubing should employ protectors for the chemical injection line. 9. Run in hole to bottom or near bottom and circulate mud out of hole with 10# brine. Add biocide and antioxidant type corrosion inhibitor to the annulus by reversing annulus after the well is displaced with brine. 10. Pull back up hole to correct measured depth taking care not to mash the chemical injection line. 11. Place tubing with packer at 5000 feet and tubing hanger in full tension. If TCP guns are used, then the BRA will need to incorporate a gun release sub. 12. Run correlation log as needed to place the guns on depth. Space out, make up tubing hanger and land it in tubing spool. Pressure test chemical injection line and pump through same with methanol prior to landing hanger. Lay down landing joint. 13. Nipple down BOPE stack, nipple up Xmas tree and test same. 14. Rig up to reverse circulate fteeze protection fluid into annulus. Pump 25 bbls of methanol or diesel into annulus and shut down. 15. Rig up wireline and run and set tubing stop and PX plug below packer. Pressure up and set packer. Retrieve plug and tubing stop. 16. Nipple up production test separator and prepare to drop bar perforate. 17. Perforate and test as instructed. Secure well, and move rig to next location. ILIAMNA DRILLING PROCEDURE REV 100CT.doc Pelican Hill Oil and Gas, Inc. Page 14 10/10/03 e e ATTACHMENTS TO DmLLINGPROCEDURE 1. Survey Plat of Location 2. Topo Map of area 3. Aerial Photo of Locations with Pipeline Route and Stakes shown 4. Mud Program - MI Drilling 5. Proposed Fracture Gradient and Mud Weight Chart with Offset Mud Weights Plotted 6. Cement Program - BJ Services 7. Proposed Wellbore Schematic and Hole Volume Calculations 8. Location footprint drawing - VISIO by Quadco 9. Diverter Stackup Drawing 10. Diverter Cleamace Drawing showing Knife Valve Placement 11. BOP Stackup with Surface Wellhead and Spacer Spool 12. BOP Stackup with Production Casing Wellhead and Tubing Spool 13. Bell Nipple Drawing for use on all three Nipp1eups 14. Swab Kick Tolerance Chart 15. Pressure Kick Tolerance Chart 16. Koomey Unit and BOP Equipment Hydraulic Fluid Requirements 17. Proposed Bit Program 18. Proposed Drilling Days versus Depth Curve 19. Proposed Completion Schematic 20. Proposed Xmas Tree and Wellhead Equipment Specifics ILIAMNA DRILLING PROCEDURE REV 100CT.doc Pelican Hill Oil and Gas, Inc. Page 15 10/10/03 .·t R ~R--~ 3601 C Street, Suite 1378 Anchorage, AK 99503 (907) 272-1232 (907)272-1344 Fax info@petroak.com . 2.63-/72- .2C0-/73 . Mr. Steve Davies Alaska Oil and Gas Conservation Commission 333 W. 7\t1 Avenue, Suite 100 Anchorage, Alaska 99501 Fax (907) 276-7542 RE: Pelican Hill Oil and Gas, Inc. lIiamna prospect seismic data Dear Mr. Davies: I have interpreted the seismic data in the lIiamna prospect area on behalf of Pelican Hill Oil and Gas, Inc. In the course of my interpretation, I saw no indication of any shallow gas accumulation in the area on the seismic data. Specifically, I observed no amplitude anomalies, phase reversals, or gas chimneys on any of the seismic lines at a depth of less than 2000 feet. The lIiamna #1 well is located approximately 750 feet from the nearest seismic line and the lliamna #2 well is within 100 feet of a seismic line. Unfortunately, I cannot provide you with a copy of any of these seismic lines because the data are proprietary and Pelican Hill Oil and Gas, Inc. do not have any rights to show the data. Please let me know if I can be of further help to you. ,cerelY, DAb ~ J c e "--'~ Paul Daggett Staff Geophysicist & e e MUD PROGRAM July 21,2003 Pelican HiH Oil & Gas Anchorage, Alaska ATTN: Arlen EhmJ Allen Gross Ref: lliamna 1, 2, & 3. Gentlemen. Enclosed is the mud program tor your upcoming Iliamna casing drìlling program. Included is a wen summary, economic summary. interval summary. and the project team. At the end of the project all unused material can be returned for tùll credit if it is in sellable condition. This program is for a low solids gellgclcx fluid in the surface interval and in thc production inter- val. Mud weights up to 9.6 are expected. We recommend that a well control contingency stock of 1000 sacks of barite be maintained on the West Side of Cook Inlet at a readily accessible: loeation. All material shipped to the \vest side can be returned t()f full credit as long as the lnatcrial is not damaged. We also recommend that careful planning is utilized to minimize fluid volumes and maximize the potential reuse of all drilling fluids. Please caU me if you have any questions regarding the mud program. Lee Dewees pf(~jeet Engineer M-I Drilling Fluids 907274-5533 M-I. Drillíng 'uids L.L.c. 72\ West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 F¡L\ ~........ i........·.·. ... DRW"'; r~.FlUIDS e Well Summary c.t'íg He. Sia Sb (in) (Iìí) ClÜilìg p~ i 5,18'" 12 1l4" C;f!IÍI};8 .5 lt2" 7 71'8'''''''' C:aS:i'\t /'*ts II e 1 Jfell (Ton/rol Gus Alck~c" K L l\'tfUi e 2 Solids K /,\'sue 3 Hole ,,-S'ftt1bili(V {'()tll ..Yttlbili(V Key IS,"llt? 4 f"'fuids (111l/ (~lIt- til1gs J., lllulgel1lent .. M-I I)rmin~Fluid~ I..L.e. n 1 W0!1tF'irS'l A\lmœ Á.nIò:;lrorage. Alaska ~ì'}~J E (l~J7) 274-5564 (~)lJ1) 219-6729 F'ílX e Iliamna 1,2, & 3 ~ (n) TVO Mud S)IØiI:m MUd SliM ~11Wì ~ 0.111 Mud GMt M) C~ 600' 600' Ge:vGelex 3.&..95 4 $lt200 5500' S$ß!)'Flo~~!IJ.3 % KCE 9..6 11 $24150 ., 1\<flJl4utlÙn ool~tant ,attet'1tìOI1 fOl' shªliowt~lSk¡c;ks, ., J\'wntain adeqWfite b@rite ino¡¡.en!\.ory. · It IS ImIX)ftant to mwntwn LOS at le.:s$ thar) 6i1o'~ to aCCOtn1f¡(}· date cas,mg dnlhng operatlotl$ · i\dd SP 101 andP1(,Jypac tIt (L'} requtred · Add AsP"..)1 $urnen»e (@ 2to 6 fW,)Utu:Is pet' barrel only ff S&OObr.bÜlg ool:d becotnes a proble..}), · Ophmize the use of aU solids OOil'rot equlpntent. UdU:ze mud clea:net on $urface vQhune \Ilith tline sçreens·. · \Vbenpo~íble r~"')'cle aUt1uad.. ~... .................. ... ..................... Oil.·. LLIIG...· .. . .....' .... . FLUIDS _. .. " . . .....', ,,~. ." , ILIAMNA DRILLING PROCEDURE REV 100CT.doc Pelican Hill Oil and Gas. Inc. Page 17 10/10/03 e Economics S,ummary e Iliamna 1,2, & 3 , ~f~~;!)t~ã-~r'·"~.·.:~~r-~ "~~íij¡'~~;':'":~ ·,:::'.,:·.··.,:~,~~~,t~~~··~i:....,' ..~: ~';·;""iI.~.Y!!l ·:·,;("...~$.·.CO'þ:' ... ' . ..' .,.,:(".,..:,,;,'" '. ..., ....,i..'..· . (If· ,. '." ($f ".,'. '.. 'IS ..... . " ,. " :." ,., ,.,. ,., ': ..'.> .. .... . ,:::.~> " .. ,:;,:: ". ,:' ·.i.: ",::~,..,...'~,.:...:.(.., .:.'..:..:".'..':.."....,:::....,':'...'~...:,:,',....~,:,.. .:.' ::':' :~':' ':" :'" ~;'~<::::~':~;"~;:"..:~:':;:::~;~,'~'.:... i:':: '. :\~.,.:y. :"?::: ~ ' Surf~ 600' :$5600 $2600 $8200 4 4 Drillil18; 5550' $12000 $4550 7 $24750 II 1IIIIIIIIP' __ · ('0$( lnch..œ$ 8 1/2" s;urface J>tlot 11(}le · full fane engmeenng servu::e H, mcluded 10 ,''Os1 · ('osts do not inchbde ImY coo~deraÜon for to${ Cif·culadon Of' stuckptpe, M-[ Drilling Fluids LL.C. 721 Wei1F'jI':štA'íi't.~ /Uk:;büragc, Alaw 9950 t (907) 214-5564 (907) 21'9-6729 Fu DRILLING FLUIDS ILIAMNA DRILLING PROCEDURE REV lOOCT,doc Pelican Hill Oil and Gas, Inc. Page 18 10/10/03 e In'terval Summary -- e Iliamna 1,2, & 3 1600' 12 1/4" Open Hole Orilting Ftuid System GeS-Gdex I I Key Products MIGeII Gelext' Baritell\>ly Pac UllSodaAsh/Desœ CF¡ Salkls Control Shakerl DeSHterlCen:trifuge Potential Problems Ú,)st CirculatiQn i I Drm Solid$l Hole StliliiHtyl Sloughing CoallBitBaUillg ~ -"' ", ,.---. -....." IntervalQriUll1gF,luidPropertles Depth iIttiltt'llM tit) 5(1)' Mud Weight (PPlt 8.895 15-25 Plas.tic W",CMity tèp) 20-25 Yie1d PðiN flhliOOfP) 25- .'5 API Fluid loss fmU3OmfA) 8- to G&í StNndth tlbliOOW) 12iJ5 Total Sòlift f%) .,..." , · Budd IJ1Hlal \;()Iume wHh fresh Wa1eï, !:; pJ1<b (')f Ml Get <1elex ~"n¢ bag (,t" (ie'lé'x f)è! tì'o'é' sacks of MJ (jel'~ soda ash as tè(Iult'ed, and battle to 9.:5 F'f'g · Open h4.)le to t2 /4" · ('f J · Keep dIm ~)hds to anunimuU1 by aggre~slve use of aU sohd'ì 'XJ\lllfQI equipment, dt!uhQn \,",,'tfft fresh waterm~ be requit'ed. · l)se Ðesto CPt() thin the mud ìfrequin~d. · Spot LCM r~m .r lost C:trCiulatioft OCCiUf:s, ., Run ~Ca$íng and deatlpít:s. for newf1o~PfO !\J)'stern. · 11~ítjal ~~%e requiretuetUs sht,}uld be 400 bbls: M-I Drimi~ Fluids LL.C. 121 Wæít Fif'-'t ^IlefU .Á.I1c11Cíl'age,AJa!lka >I)I)$() I {91J7) 274-5564 {9fJ7) 279-6129 Fa:>; DRlLLIfUG FLUIDS ILIAMNA DRILLING PROCEDURE REV IOOCT.doc D.....lTO 10 10/10/07, Dol~"'Or1In LT~11 (,,\';1 .........,.:¡ n."'C" Tn,... e Interval Summary - e Iliamna 1,2, & 3 5500' 7 7/8H Hole 5 1/2" Casing (drilUng with casing) Drllln9 Fluid System (Jel<~lex Key Products MI Gel I (1e1exl BIritelPOIyP¡¡ç VI/Soda .4$h/De:soo CF."SodhJtI1 Bi~ wbcmatelDO Solids Control :)}.~....~r.:;(fli!,;;';f'~l!:.~~2~~;;:; .- Potential Problems LœtCirculatiofi / Drill SoUd.·,/ HQle ;StabUi.~'l S~OU&tî~ h'tg Coal/Bit Bamt1i Interval· Drilling Fluid Properties Depth lätéN.at tft) IO{)D' j,toolr .............~. þt;/l:!itiC Visoosfty tcþ) 12.;20 Mud W'ìMght (pp.n 'l5-W.Ü HU) 12-20 . --- Ykdd ~ 'lbI"~ A~ FloW Lœs tmUaOmifi) Gèt $tænglh tlhf100ft#) 8/H OriÜed SoIkM (%) <5~~ ~. 12-20 8-W <6% r ..., 12-20 () - 8 .. ............- .". m/l$ · T n~!lt surface mud tcn cement coníammaW.m \.'tiiuhS().(jtûn, bll::~(bof1ate and D~c() CF Run $ØI~ !d,'ìconttxll e<tupment Rutl nmd cIeaner\V'íth 325 me-sh ~Cleen$ ~)tl $urface vohm1e pno! to dnIHng pJoducuon mtef'Va1. · Imtial mud we.!f;ht should be 8.8~9.0 Pl)¥· Unless bole C()11dUíO<fU:¡ d1i.'Ulte odler\\i1s:e. · Keep drill sohds to tess than Mcf¡, by ~~t'eg~fVe ~<;:e of aU solids control equlptnent, and dth.rhon if fel;lUllJ'ed .. MaÎfìtronfluid IQ!,;s Ç¡{)fttf'o1....,1th additions ()fPoly PacUL · Inítild\l(}lume fequín.~Inen;s should be 600 bbls M-I Df'imn~ Hum L.L.C. 721 We!rtFi¡rm A\'L~1.IJi.' Atw1kir., AI¡¡¡!dœ 9')5.0 1 (907) 274-5564 ('Xm 21~6729 Fí1x ILIAMNA DRILLING PROCEDURE REV lOOCTdoc Pelican Hill Oil and Gas, Inc. Page 20 Fm....... / .. .......... aRß,..LING . '.. ... PlUIDS '!!."...._.._., ,_·c,_·· .. 10/10/03 e L.CM Guidelines- e Iliamna 1 ,2, & 3 '·~..,C¡rçl.(tatl(Jn' lost Circulation Recl,)mmeuded lCM pm Fonuuta,.;:¡ Problem. Key Products DdlUn.gFluid l M..I SealFine~ Medium, CQan¡e I X~ Polytner Form .A Se1lSafe Carb 10..20..40 .' ... . ·C· .~. . . .,... ... .. ·P'·· ·····1/8· .... .. h· ..... .'.., ......... . .. Lóst>ltcUâtlöh': "",:Ilg .t'Ltìssêsr . . . . . '. . Voh.ìne of Mud CbBmliM) 30 MtJUt Fine ffJÞD) 15 M..¡ Seat Medium fppb) o ,..- M.f Seat c.oan. (ppb) () lost Circulation Pin (Moderate Losses) VQlume òt'Mud (bam!Is) 40 MUth Fine (ppb) ,.. SéaJ Medium Cppb) 2(1 20 l 'W..I .Seãf¡ ·Cöanè ....) o . Lost Circulation PIli (Severe losses) VofUmé of MUd (bam!~) 50 _XI fine (Pþb) 20 I\W IBM Medium fppb) 20 . Spot ~he pm &::1'0$$ the I(J$:\> }'"one. . 1.Jse MIX Pine when1\>I\\,'D andl()f tnudnh:,)tm' are being used. !it tJse of Sa.tè Carb pt'ooucts: as requil'e'il M-[ Dfmii1~ Fluids LL.C. 721 We!!t Fir~ A\'t!'ÌJ1:1I£ AiJ.:JbOl"3{ti!, AI¡¡¡!lb, 9'}50 ! {OO7) 274-5564 (9Ü7) 279..f;niJ Fa:" ILIAMNA DRILLING PROCEDURE REV lOOCT.doc Pelican Hill Oil and Gas, Inc. Page 21 M.f SUf CoatM Ippb) 10 . .. I }t..C I Polymer ....) 1/4 _...I }t.;(; PoIymtf I...) 1,"2· - x..c PoI,....t .....) J DRILLING FlUIDS 10/10/03 ~. 10î1'· . ~1ï.; .. r4bd. VfèiA~· .~ _riaï .. Ø94e "ight . ""riBl $G ~~ht.. ~riaï .þt~. ~.~..... .- $$8 s..lt \4,.1 Géf li-I Get 'rlëè # Products 1 2 J 4 5 ~E.lEX Sodium Bicarb .sP·-101 ~Ol YPAC Ul Caustic Soda 4'-'hrome--Free Desco ~-D ~ar1 "3e1 ¡vater 5 ., 8 9 10 ~N6I .' , ,.' I T-r'" ,.' '\ ''I. .. Ie ..... u..~"_iGht .. .., mI!IJ¡I, . -- M-I )fimtl~ F1um LL.C. 72IW~sIFirj( AV'Ì.iif1'OO Ancblìf<lí:@ìi!, ,\]JíìSU 91)501 (X)7) 214-556,~ {I)I')7' 279-1:i729 Fax e . Gëf Gèlé( S)'s- ..·tem '9.2 &t1 4.2 0.1285 Nô No 15 0.1393 In_ OütDut..1 bbI ConCén- Iration Fièld.lb 0.02 0.20 1.50 1.00 0.20 0.2~ 0.50 301.58 15.00 333.15 ,386·1 ILIAMNA DRILLING PROCEDURE REV 100CT.doc Pelican Hill Oil and Gas, Inc. Page 22 Lab. ant D.at D.~ 1.~ 1.~ D.l( O.2~ o.~ J.4. 15. 333.1~ 386AI 9.2OCt va&- ,.m18 Field. bbl O.o~ o.oOC: 0.004 o.oot 0.0C< O.Ooc; 0.001 0.024 0.01f( 0.95~ 1.0oct e ~ l Lab. ml 0.01 0.09 1.43 0.63 O.OS 0.1< 0.50 ð.2J 5.17 333.15 35d 10/10/03 ColSit 1 bbl 0.13 0.08 3.16 2.96 0.11 0.49 0.56 4 ..f.4 2.09 0.00 14.03 DRILLING FLUIDS e HS,E -- Iliamna 1 2. & 3 " .." . e HANDLING OF DRILUNG FLUID PRODUCTS HEALTH AND SAFETV I ,DrUHngcrews should beínstructOO in me proper procedures fOfhandling fluid products, 2,PersonaJPfotectÎve Equipmoo1 (WE) charts should be posted in the pit r~. the mud lab. and the office oftbe Dtilfin~ F()finm:\. . ..' , ". - ... -,. . . "m!-,. 3 . PPE must be in good\.vorldng (tî'der and be udlizedas rect}m1Dended by thePPEcharts. 4. Product addifÍ~m.iJ. sl'M;Juld be made \~th the iutetI! to u.,,,e oomplete unit MIOUí1tS; of pt'OOUi(.i~ (sacks. drums. cans) ~ Itluch as l)t)S~ble in t)tderto ¡uinhï'ti.ze inventory ()f ptU'tial units 5. Ins:w'ealIM$DS sheets are "ut) to date and re.adHy available t:Orw'Of'lœrs t08.l.'Ce$S Î(u' Intòrntaboli. ENVIRONMENTAL 1 ,Insure that all ~)roduet stored (,)tArstde lS f)'fOtected from tbe weather 2. IJ() t}utstQre I*hal W11fS butcks, etc) outsu:fe without OOdttl.QI1a.! pirotechOí} -'. When tran!itè'1'lug fluid and Oil' (uttingsft'()t'n me rig t~') tallks,lusureaU Dt)$eS are l'Jtt)pe:r1y secured. M-I DriUìt'S Huíds L.L.C. '121 WIo\'i¡;;1 First A \'(.,'fID¡t¡! JI,ndl)f~" Alaska '\)9)1;) I (901) 274-5564 {'907) 219-6729 Fltx DRILLING FLUDS ILIAMNA DRILLING PROCEDURE REV 100CT.doc Pelican Hill Oil and Gas, Inc. Page 23 10/10103 e HSE e - II ¡am n a 1,2, & 3 (Includes contingency products) Product Function M-I BAR IM-I GEL løELEX IFLOVlS IDUAL-FLO IPOLYPAC IHIC IBlOZAN IGUAR GUM ISAFE-CARB F ,M,C ILOWATE INut Plug I~ Seal F, M, C IMIx II F,M,C IRESINEX ISOLTEX IASPHASOL D lcesco CF IVENTROL401 =:-IG-SEAL ~111l! l'nOO!l Ld.".L.. ì21Wß~lFíl:!ìt A\'m'we l\l1cl~, AJa!lka ~jil.) I (9(7) 27;4-5564 (907) 279-6129 Fux ~.wld~j Agent ~'h-i!!f.Î!Þ'!~'" control 1:r:mrt'\'¡U(~' Extender L'~,~. .. n,.c;¡,"l,!·t':u.fì:4 1;~lriIÎ!if~rqÎ!i Starch 1~!Im Loss Reducer ..'J.i:'; Circulation Mate~ rim ~'lJ.i~ìJ..iler:4' ~'J~tt:4' ~...... ~r."~. and weighting ~... ~¡HJ'IiT*1 agent I.ì~i-~ Circulation M ate~ I'if.1 1.,iï}:'1;.1 circulation Material 1.'J..i--i circulation Material ~: Fluid Additive I:!'lí:: stabilizer I,:mr:; Stabilkzer l.l~"J.r~t.i"-;1ìF (:m¡ìm~' ~. Fluid Additive ILIAMNA DRILLING PROCEDURE REV lOOCT.doc P~lk::m Hi11 Oil :mò G:I!': Tnc P:lP-~ 7.4 I · · II · II II · II II · · · II · II II · II · II , .., r~1flIr 10/10101 e e HS,E - II i amn a 1,2, & 3 (Includes contingency products) Product 'CAUSTlC SODA 'CAUSTlC POTASH IBORAX ISAPP ISODA ASH SODlUM BICARBONATE ICITRIC ACID IMVACIDE - IGREEN CIDI 250 . DEFOAM X - BUBBLE BUSTER I KlA-GARD ILUBE TEX ID-D CWT Concor 303 SAFEKLEEN ISAFE SOLV SAFESCAV NA SAFE SURF 0 soDiU M 'CHLORIDE ,.._,,---- , "",.,,, POTASSIUM CHLORIDE- M-I DftUìß! Fluid& 1..L.C. '72 J. We:!rtFirst A\';eal\æ ÁJ1(;ht1fi!\8e, Alaska 9')501 (~),J7) 274-5564 (907) 279-6729 Fnx Function ~.~., ,. jOii'V'l""-' r.o;~'I~~;!f1hl~' ....... IV VI ~= Modifier ~wr.u.. Borate ~i';!=Wt~I~' Pyrophosphate '~'~tr=VlJ control ~~Ifcontræ ~: Adjuster I:l~r.[::; r:'~r· l·n'i,~L.~.:i 1.T;U'f;rm~ ' 1~~t.J;I'm~· l;iimr::: Controf agent ....,mrilf;:¡· U. ItI:} t=!ít [;oJ. r (Ç{l.ßU I I nt1ìbìtor I!JiWW!jftuld additive tt:~n'J[:}u"I') fluid addi~ ~'r!,riW scavenger ~. '.'. !.!':m.]" fluid addi- ~ ~...,...,. .t~nItJf'fluid addi- ~ t;;,i'mr:.: Inhibitor Doli,.."'..... u.¡n A'¡I ...."~ n.....C' Tn,.. ILIAMNA DRILLING PROCEDURE REV lOOCT.doc Dr.tITO 1, - - - PPI x I X I I I I I E I I I I I J I J I J - J J J J J - J 'lÌ2 1 'I 1 'I J I H - J E I - ...,..... ........>..... ... .......... DRlU.IIG ,~ FWlDS 10/10/01 e e HSE -- Iliamna 1,2, & 3, HAZARDOUS MATERIALS IDEN'nFICA 1101 SYSTEM (HUll) HAZARD RATINGS .. - &.wire hamrd 3 ~ Sertoua hazard 2 - Modinté hazard 1 - Sight haard .. - Minimal løiard IÍ M Mlerilk í'IiId to the hulltl rating Îfldici!Iéš that ,. chronic hazard 1$ ~èI_d WiIh the m~L MMIS PERSONAL PROTECTIVE EQtIPMÐlI' INDEX A - SøfeIy Glauu B - S8féty Glauu. GlìWü C - Sa. Gl8saê&. GlóYü, S:ynlhelic Apron Ð - Face Shield, G40vø,Synthe1ic Apron Ii - Safèty Gltl!&ä8, ~,~t R_ImkIf F - SiWty GIau_, Gtov_,$yMhelic Apron, Dwt Røpîr8ttlr G - Safety GI.._, Gkwés, Vapor Respirator H - Spltih Goggkm, Glòvø. Syt'llfï&ticAproo, VC'tfJ« Rapkal« 1- Safety 01..., Glow., Dust and VapOf RlMIPirmor J - Spl.... Gog~, GjOYeS,Synthe1ícApron, Du:at and Vapor Respirator .K - At Unit Hood or Pd_, Gloves, Full Süît. Boots X - ConSUlt your. $UpéfVisorØbt apedat handing ditttdion& M..I Drillin$ F111¡,j" L.L.C. '721 West Fir&it A'!l'ßßœ .Â.flC1){)r., AJ¡¡¡WI {)It)j!H (901) 274-556,. {(~)1) 279-6729 F.~ ILIAMNA DRILLING PROCEDURE REV 100CT.doc Pelican Hill Oil and Gas, Inc. Page 26 .r'P"fj. .......... ..... .... ... .. ........... .....rJRII,LIØ ,~ FWIIS 10/10/03 e Project Team e Iliamna 1,:2, & 3 t . . '. . I ." ['-'.' '.' J............ ,.. .... (::r"'''__ PI ;:¡~¡: 7::~;:~:('1 ; ~ ':.. ót¡lri:·MaDàger ~--~- --.. -. -,- C1œ y,!':¡k I w_......p Willie RiJ~lm¡J t ].. .........................................'.......................................................................................~............................................................................'......t;¡........................f\I'.Ii......................,'.......·.....·.·..·...·.ü..·.·..·...........................................'................,.......,................................................'...........·....·.1 .:-::........'--......--..'....'-..- - ,'",.-',', 'J'tI(¡b~Ïêê·.··.··.·,·.······.··..· ..-.-, -.. .,..",. 'IIIIF-:'.lll . I . Ml Projoc; Et1~ìí)t.", ;ißJd /1.'>.::1'1 &:I'\'j(;,¡! Eílg~t)t.""1 wiU ¡;(k"l'dj~t;¡ N'I\\L'Cn 11fi.! I'if!. Wilro!t'IWO, and 1hz :!i.H fidd eugitTIC\lls. . Wdl r'mg;lte'.\ì:s \¡,ìJ! lx' m(tlulüitex! to kx,k fill nt1~ ¡;Jläfig..~ ....lü¡¡:b \\iII UnplÚ\ê the 0Ifù:iL'1T1C\ of lbe ü)L"ta- Ü"'I~ (It ;1\'\:lt b\,ublf~. Project 'rCnAn CraigBlekl' I"ítk Dlltrf£tM~.. Deen Br,iIII L«:De1I1!Ö Tedt Sienia! Gu Wlk proJeetEø3lDee:1' W'a....1lí1Ule l'tbnaJu Fie" E~r J'i1tf¡d E.eer PIdIU, Hupa MOIlte Kanta M·I DIi:mtll;!.,Fìu¡d~ LL.C. 721 We.¡¡IFil,¡;t A\'L~Ì'œ Ancbüra~, Alalika 99511J I ~91)7', 274-5564 (?::)1J 27',),,6729 Fax ILIAMNA DRILLING PROCEDURE REV lOOCT.doc Pelican Hill Oil and Gas, Inc. Page 27 \V ork 9t7 2'...... 91Þ7 27....!OOJ 9t7 27....s..~ 9t7 71'-1JQ1O 9t7 17"~MW 9fi7 :174-5564 Cellular 9ð7 U!MJi96 9Ø121J...Ji4íJ4 907 117. 9Ø11~24:!18 DRILLING FLUIDS 10/10103 PROPOSED FRACTURE GRADIENT AND MUD WEIGHT CHART PELICAN OIL AND GAS 1 OFFSET MUD WEIGHTS, ANTICIPATED PORE PRESSURE, FRACTURE GRADIENT, MUD WEIGHT, AND CASING PLAN l 4000 ~ G/J Q ~ .r: i Q 2.875" 6000 7000 - 8000 9000 - 8 9 10 11 13 14 Mud Weight, Pore Pressure, Fracture Gradient (PPG Equivalents) 12 ILIAlVtNA DRILLING PROCEDURE REV lOOCT.doc Pelican Hill Oil and Gas, me. Page 29 Gassy Coal Gassy Coal t CONGLOMERATE t 88~1 t 88~~t8~~~~n . Coal Coal Coal . Coal Gassy Coal ~ A~~¥ 8~ Gassy Coal Gassy Coal Gassy Coal . Coal Coal Coal Coal CONGLOMERATE Coal Structural Casing ,. Surface Casing Production Casing Iii! -"'ProductionTubíng -PROPOSED MUD WEIGHT iUAMNA 1 ANTICIPATED PORE PRESSURE EXPECTED FRACTURE GRADIENT Forelands State A No 1 KUSTATAN No 1 ,_@wvwa«wwMOKUAKIE No 1 ANTICIPATED CONGLOMERATE ANTICIPATED Low Gas COAL BEDS ANTICIPATED GASSY COAL BEDS I I I I 15 16 20 17 18 19 10/10/03 CASING PROGRAM, CASING SAFETY FACTORS AND HOPE RATINGS PELICAN HILL OIL AND GAS INC. ILlAMNA CASING PROGRAM AND CASING DESIGN SAFETY FACTORS CASING RATINGS AND DESIGN FACTORS STRING CASING OR TUBING SETTING FRACTURE FORMATION ASSUMED MUD FORMATION GAS DESIGNATION DESCRIPTION CASING OR TUBING RATINGS DEPTH GRADIENT PRESSURE WT PRESSURE GRADIENT MASP DESIGN FACTORS TENSION JOINT TENSION COLLAPSE BURST SIZE IN WEIGHT IN RATING IN COLLAPSE BURST @ SHOE IN @ SHOE IN @ SHOE IN IN PSI PER based on air based on with Gas NAME INCHES IN PPF GRADE POUNDS PSI IN PSI IN PSI FEET TVD PPG EO PPG EO INPPG PSI FOOT PSI weight empty pipe to Surface STRUCTURAL 13.375 54.5 K-55 853000 853000 1130 2730 80 10.5 9 10 37.44 0,1 29 195.64 27.16 94.14 e SURFACE 9.625 32.3 H-40 365000 254000 1400 2270 550 14 9 10 257.4 0.1 202 14.30 4.90 11.24 PRODUCTION 5.5 15.5 J..s5 248000 248000 4040 4810 5500 16.5 9 10 2574 0.15 1749 2.91 1.41 2.75 TUBING 2,875 6.5 K-55 99660 99660 7680 7260 5200 NIA 9 10 NIA 0.15 1749 2.95 2.84 4.15 MASP Calculations are based on the anticipated formation pressure minus a gas gradient to the surface and assumes the well is completely unloaded for the purpose of this calculation. Collapse Safety Factors are based on the Assumed Mud Weight Hydrostatic with the tubular completely void from the surface to total depth of the string. Tension Safety Factors are based on the Air Weight of the tubular string wrth no buoyancy. CASING DESCRIPTION AND SETTING INFORMATION STRING CASING OR TUBING TOP OF DESIGNATION DESCRIPTION THREAD STRING SIZE IN Wl:lGHl NAME INCHES INPPF GRADE TYPE FEET TVD STRUCTURAL 13,375 54.5 K-55 BUTT SURFACE SURFACE 9.625 32.3 H-40 BUTT SURFACE PRODUCTION 5.5 15.5 J-55 BUTT SURFACE TUBING 2.875 6.5 K-55 EUE 8 Rd SURFACE BOPE TO BE NIPPLED UP ON TOP OF EACH STRING SElliNG HOLE STRING DEPTH SIZE DESIGNATION PSI FEET TVD INCHES NAME TYPE SIZE EQUIPMENT RATING 80 14-3/4 STRUCTURAL DIVERTER 11" HYDRIL 3M 550 12-1/4 SURFACE BOP STACK 11u ANN & 2 Rams 3M 5500 7-718 PRODUCTION BOP STACK 11" ANN & 2 Rams 3M 5200 NIA TUBING BOP STACK 11" ANN & 2 Rams 3M e ILIAMNA DRILLING PROCEDURE REV 100CT.doc Pelican Hill Oil and Gas, Inc. Page 30 10/10/03 e e BJSER~CESCEMŒNTPROGRAM P~í1Id for. Ji\m MÖIMIly Projed Engi~ Pelican Hill Oil & Gas, tne, Sètvice PoInt: KéI'1at AK Bus. Ph(Jnì!: fäJC WJ Pröpcal No: tOO11i968F' Pelican HII Oil . Gas, Inc. Iliamna No.1·.. REVISION Pélfœn HII RIg IlImnna FI.ld FkIfd Anchorage C(JWìf)', Ataskã Odôbèj' 9,2000 Well Recommendation Pt'êp¡ved by; J.. JilyGiltnêf Manäger, City Sal. Kenal.A.tastta Bus Phone: (901) 349-6518, Anchorage Emal: prn_Objséti¡iiœt..oom Mobík!: (901) 229-6536 : f' "'~ -... I? () \\' I~;RV I 81 ()N' ¡~ (901) 176-4084 (907)659--2:329 (907) 178-4087 ILIAMNA DRILLING PROCEDURE REV 100CT.doc Pelican Hill Oil and Gas, Inc. Page 31 S4!1rva ReprestntatwiR: J. Jay Gamet Managéf ,CiI.ySilIM Kènai. Nash Bus Phone: (901) 349-65 la, hlchorage Email: jgarner@bjsefvicM.oom M()bile: (901) 229-6536 10/10/03 ~rName~ Pelican Hill Oil ,,,,..IM. WeI Namè: lliamnil No.1· Job Description: Conducmr Caaing DMé~SeipMmbèr 26, 2003 e WJ Pmpoul No~t oo119958D JnB ..AT A GLANCE Dêpth (1VD) Dèpth (MD. Hole Sia SOft SOft 14.15 In CalngSi!elWøight : Puínp VIa 13 318'-', 54.5 Ibalft 13 3J8!! 0..D.(12.815'* .tD) 54.5 90gatSì I_I Mix Water Requtfed Spacer fft!S1h Wamr Dlhlity Cêment &furry SUrfâCé Pipe stuffY Dlhsity Yield 10 bbls 8..4 ppg Dmplacement Dispíacament Denlity WFU nATA 1 e stlldl.$ 15.8 ppg 1 .16 cff$acf( 10 bbl$ 9.5 ppg ~""'L.A It GFOMF.'TRY .~mJ¡ "J~n f,-:-'- @t) 1..150 HOLE 11 ;:¡~î~Ti':¡ .Tr~';;JTr"~''!'~ ~aT"~T';';¡;_··"" .,. .' ..;',~.'. .i;;¡~_I.pJ.,.j~,u,to:r. 80 I 80 I ,.,,,,.,,. SU8PI;NnFÐ .PI£a. .}fJi'.1 ;;jÎ;:ji..trn Il:;i ,:lI~fIlJ ,~J :j.:.'r;lmT~'" .i~l'r~Tj';:f;iÎr~l. 64 I 64 I O.D. iTiJ..;¡¡ 1,ij j ...~. I 54.5 I 13.315 12.615 Mud Density Mud Typo E.... Static TémP. E.... Circ. Temp. 8.42 ppg Water Based 55· F 55· F VOLUME CALCULATIONS 84 ft x 0.2109 tUft with 50 % èXcøs = TOTAL SLURRY VOLUME = 20.2 cf 20.2 cf 4 bbI$ = ILIAMNA DRILLING PROCEDURE REV 100CT.doc Pelican Hill Oil and Gas, Inc. Page 32 10/10/03 e e OpentIor Name~ Pélican HIli 011 & Ga, Inl!:. We'll Nar:ne: IlaMI'Iia No.1 Job Deuriptiðn: CótldtJiCfdf· Ca&ing Ðate<~ SeptémblK 26, 2003 Wj Propoul No~100119958D .FUlln SPF-ClFlCA TIONS SpaCéf F'tmD CëmêM Slurry 10.0 bí8 Fí\ê$m Watvt· @8.42 ppg VOLUME VOlUME Cu.n fACTOR AMOUNT AND TYPE OF CEMENT 20 J 1.16 II 18 uck& Clüš G CëmêM + 1 p1ti100 &8ek FP- 6l + 2% bwoc Calcium Chloride .. 44~3% ~Water 9.9 bbíä DI8pÍ¡ijCémêM @ 9.5 Wg ChptaCêhUìN CEMENTPROPER11ES SLURRY NO. .. 15.80 1.16 5.œ 5.01 Slooy Wéfght Cppg) Slurry YieJd (cf1sack) Amount of MIx Waller (p) Þ.mounc of Mbe Fluid (p) RHEOLOGIES FUtlD Spacer Product Mat8rial QTÝ UNn' 18 sadœ 341bs t gals Service Chargu QTY UNIT 12 hrs 24 hrs 19 cu It Equipment QTY UNIT t 4hrs 1 job 1 Job 1 job 'RIIP @ 5!PF ao 129 Hð 100 2M 91 10ft 91 1& 36 2 27 fRICF FftTIMA T~ PAODUCTœ~ NE.T AMOUHT 305.91 19.62 36.85 $362.58 Clau G Cement Calcium Chloride FP-6t . Product Mateliál Subtotal: PRODUCT DESCRIPTION NET ~ 661.65 1.082.«<1 28.01 $1,m.os Senriœ Supervisor. hourly marge: Equipment Operator Dry Btdk Matefiall SIIt\IIQ! Charge: Service Chargu Subtotal: PRODUCT œSCRlPTION NET AMOUNT t,212.75 222.75 577.50 517.00 $2.530.00 $4.6I4.t.4I Ce:rnentPump Casmg. 0 - tOOO It Fu-.Løk. Cernënt Head Data Acquisition, Cement. Standard Fletd Storage Bin Equipment Subtôlat~ TOTAL: ILIAMNA DRILLING PROCEDURE REV 100CT.doc Pelican Hill Oil and Gas, Inc. Page 33 10/10/03 e e ~oø AT A IU.ANCE Dèpth (TVD) Dèpth (MDI Hale SIM 550ft 550ft 12:25 In CìlslnaSI.!è#WtIWd: ~ Pun., Via 9' 518." 32.3 IbsJIt :9 511" 0.0. (9,t)01''" .I.D) 32.3 1.351 gala Tctal Mbc Water Requlnd Speœr frHÍI Water Spacer Density Tail Slurry Tall Cement Density y1etd Dmliplacemènt Dilling Mud asptaCflflW'lt Density 15 bbls 8:J'fjpg 1929" 14.5 ppg 1.48 chaCk 37 bbls 9.5 ppg .WFII nATA ANNUL""" OFOIIII=TRY Jj;f ~i':!:; i: ,'J::H:lf];Lf ~ _j~UJ ~ :1;.H"'~'" 64 I 64 I 5~ I ~o 12.220 CASING 12.250 HOLE SUSPENOEO PIPES ÞK"',~í1TI 0.0. .~o. ~.j;:i;;¡I:fW ~ ~¡ ;f'~~~11m;;ij~ 1II;~Jr::&Tl:;t;:..r~J. I 32.3 I 5~ I ~o I 9.625 9.001 F~t Collar.. . Mud DflMity Mud Type Ed. Static Temp.. E5t. CIm. Temp. 470ft ~t50 ppg Wätèf Baèéd 61 * F 55· F VOU I. CALCU. -"ON8 64 ft It 0.3092 cmt 486 ft )C 0.3132 cflft 80ft x 0.<U19êUft with 0 % éJ(t:éß with 50 % e)(c8'fl¡~ = with 0 % ëXCè_ TOTAL SLURRY VOLUME = 19.8 af 228.3 cf 35.4 cf(inside pipe) 283.5 of 51 bb/!s ILIAMNA DRll-LING PROCEDURE REV 100CT.doc Pelican Hill Oil and Gas, Inc. Page 34 10/10/03 ,FLUID Sef-ClFlCA TIONS SpaCM FUJlÐ Tail stuffY ~ce.ment CEMENT PROPERTIES e e VOLUE Vöt.UME CU,," FACTOR AMOUNT AND TYPE OF CEMENT 15.0 bbI& FreshWøter SpaCflf 0 8.34 ppg 283 J 1.48 ill 192 $!ÏCk$ Type) Cement -+ 8% ibwóc E!'A.90 + tt,,% bwoc f3A.10 + t gals/1M sac!{ FP-6t + 62..4% Fresh Wahw 37.0' bbfs Drilling Mud Di&plaCél'fiênt @; 9.5 ppg SlurryWélght (ppg) Slurry Yletd (cflsack) Amount of Mix Watãr (\1P5) Arnc!unt' of !lAbl' Fluid (gps) Esìll'Mted Pumping Time· 10 Be (HH:MM) Free Water (mIs) @2" F @ 90 " angle Fluid lIm (c~mIn) aU 000 psi and "F C~VE STRENGTH '1 111'$ @; 6ì. pi (psi) 15 hrs @62" F(PÛ) 24 hrs @2 62" F (peï) 120 hl'$ @ 62 .. F (psi) RHEOLOGIES FLtßD Spacer TaU SIu«y ProdUd' M_.' QTV UNiT 1ü 1èa 14441bs 131bs 2 gals 192 sacb hlvice Ch8lØ*s orv UNrr 12 hra S6hn . ZSS cu ft n;Jllp o 55'" @. 6O"F SLURRY NO.1 14.50 1.48 1.04 1.05 4:22 0.0 8.0 50 500 915 3200 ___ ___ ___ -1I.L --L- -L- 129 100 91 91 36 27 158 117 104 86 59 45 PRlr.1! F-~TIMA TF PRODUCT OESCRPnON Cernent Pfug. Aubbet, Sóttom 9-518 in CernEmt Pfug, Aubbet, Top 9-5'8 in BA-90 BA-10 FP-61 Type Cement Product Matélia' SubtDttll: PRODUCT œSCRlPTf,ON Sèt\ìÎCè SupefVÎSiOl - hourty Ch8l''Qè Equipment Operator Dry Bulk Matet¡øSeNI:ceCharge ,SeNÎœ Chargea Subtotat: ILIAMNA DRILLING PROCEDURE REV 100CT.doc Pelican Hill Oil and Gas, Inc. Page 35 N1!T AMOUNT 264.&5 143.00 849.19 525.91 73.10 1,842.72 $3,699.13 NeT AMOUNT 661.65 1,623JU) 42.1:.09 $2,105.34 10/10/03 e e .aßUI AT A GLANCE Depth (TVD) Depth (MDI HoIellze 5,,500 'It 5,5ooft 7157,5, In c.lngSImlWeWrt : Pomp VIa 51J2In, 15.1 IbaJft Tötal Mix Water Required 'WIHghlmd Spacer' MCUD Spaœr System Density 1. lead Slurry Casing DñIed Section .. Lead Density Vi81d Tail Stuny CMing..oñlhMI SactionT.D Density YIoM 1!iH1gø1, 30 bbls, 10.5 ppg UUs8Cks 13.5 ppg l:82··'dfMck '......",,,"",,.,.< ~,,"''' .d.f..'''''··",·,---......., ,,//149 sacks / ( 15.,8 ppg " \ 1..16 cfIMclt/ ., '" "~..,."""<>,....._"-,--""-"""/<"'..".... œs·. -....'. pIøcemønt'... ..... .. .' .""'-' ',' .'..,.' , .' ", ". 2 IB,LS 'C..nt ... Drlling Mu Density 131 bbls 10.Q ppg ILIAMNA DRILLING PROCEDURE REV IOOCT.doc Pelican Hill Oil and Gas, Inc. Page 36 10/10/03 e e WELL DATA ANNUI..AR MOMmv , . . III , 9.001 CASING 1.875 HOLE -·¡T::{~I:mi ~;r;'!;1fJ;1~'~ 1I¡¡ur;JJr;¡~iiF~. I 55Ð I 550 I 5,500 I :5,500 SUSPENDED PIPES .Jtlí~r;¡i;r~~' :ij:¡~i;m~ ~ ¡r,. '! l~ ":I::~JJ~Ç,;Iiï." Iffi1tJ;srIJ:f¡¡rtTJ1I 5.500 1---'4.960 I 15.08 I 5,500 5,5001 MudDBMfty Mud TDé EM. Static Temp. Est Cke. TMnP. 10.00 ppg Water Basèd 113 Q F 97 t' F VñlU,. CAJ r.... A 110H£ 2.000 It )( 0.1133 dft 1.000 It )( 0.11'33cn win 0 %êXC.., = with 0 % excMt = TOTAL SLURRY VOLUME = 346.5 cf 173.3 cI 519.8 (if 93bbJs = ILIAMNA DRILLING PROCEDURE REV 100CT.doc Pelican Hill Oil and Gas, Inc. Page 37 10/10/03 e Opendiør Name: Pélìclm Hill 011 .. Gu. Ine. WllIIIaimè: lìlamna No.1 -REVISION Job DKcriplion: Cat.i~11kn:I Casmg Sèdlon ~è~ ~bef9.200~ FLUID SPfCFICATIONS Weighted Sputéf FWfÐ VOLU_VOLUME CU.fT FACTOR tlit lead Suny 347 I 1.82 Tall stUffy 173 I 1.16 fÃíiiplãCéMéhI CEMENT PROPERTIES Slurry Weight (ppg) Slurry Vield (cflsack) Amóunt of Mix Watét (gps) Amount of Mix Fluid (gpe;) Estil1'liílled Pumpìng Time - 10 Be (HttMM) Estimated Pumping Time -100 BC (HH:.MM) Free Water (mts) (I 9ì" F 0 45 ., angle Ftuid l.øø (ccí30rnin) at 1000 psi and 98 iJ f COMPRESSIVE. STRENGTH ... hrs 0110" F (paí) 4.37 hm 01'10" F (psi) 6.35 hm @ 110· F (psI) 7.51 hrs 8110" F (PSi) 8 hrs 8110" F (Psi) 12 hrs @110 ~ F (psi) 24 hra @ 110" F (psi) RHEOLOGIES FLUID TEMP e ':~~ r.¡u ~HOì: îOOt7995. 30.0 bbf& MlCs..mSplllcw Sytmm + 141bs1bbl R-3 + ~tø.baJbbI F>MM1!lÍurn ChkJridè + 30.15 lb&Jbbí Bentonlû + 1191~ Sarltê @10.5 A~AND~OFCEMBff = 191 sacks CI_ G Cement +tG%, bwoc BA-to +1% bvIot Calcium Chloride '* 2.5% bwoc Fl- 62 + 0.2% bwocASA-30t + 2 gð1sJ1òO sack FF>- 6l '* 0.5% bwoc SodhJiIn Meta&1lícaœ + 64% Fruh Wøféf = 1491aca Clna G Cemèft + t% bwoc eA.-tO + 0.1 % bwoc R-3 + 2% bWow Potasllum Chklride + 0.6% bwt:Jc CD-:ì2 '*' 1 gltt&J100 sack FP-ðl + O.~% bwoc Sodlwn MmsØlcate + 34.8% Frøh INater 131.4 bbls 2 BBLS CémMt + Drilling Mud @ 10 ppg SLURRY SWRRY NO.1 NO.2 13.50 15.80 1.82 1-16 7.21 3.92 9.21 4.92 4:tO 4:08 4:35 4:22 0.0 1(1-0 14.0 50 50 500 500 517 972 923 2188 t731 :W32 soa 300 2M I -1- 100 1 at lead Slooy @ '96 ·--f 86 SO 37 24 12 12 Tall Slurry @ 98·~F 2$0 152 108 62 16 13 ILIAMNA DRILLING PROCEDURE REV lOOCT.doc Pelican Hill Oil and Gas, Inc. Page 38 10/10/03 e e Opi'nfðr~: PeIlt':8n HlI Oil & GM,IIìíé. Well NenírIt: l&amna No. 1 - REVISION Job Description: C.g.-Drilled CMlng Sedion Didèt ~r g, 2003 ....' ! ~ J.... ,............ ...... .. ".. .. ........ ~ "''"'--''''-''-'-''','''',',.-.,_"-'-',"',..-,:;,, ~ No¡ 1oo179958F ,PRICE ESTIMA TF! E4uipmtRt QTYUNIT Equipment SubtlJtail: TOTAL: 2.557.50 222..75 517.50 1,034.00 $4,391.75 .4, '127.011 1 .t. t job 1 Job 2 job CRent Pump Casing, 5001 - 6000 It Faa-Lok CtmèñI Heed Data Atquidon, Cement, Stattdafd Field Storag& Bin I'Ifotø 1. Final êhãtgél3 to be baHdon ac::fl.j¡a hi)UfS, pré$sUte and møœrÎàls blended for and 01' cooaumêd oo~g cementing opera.fof"tl. 2. No stand-by êhätges w1ìI bê Ìficurtéd for ttOn-opêfitting dayJi bêtweéI'JWêlls. 3. Room and board to be provided by Pelican Hill 011 &. gu. Should ibIS not be pMSîb4e remote locllltion chørge& fot personnel Will bé· ìncurred. 4. Tral1$þottatió11 fat' eqlJjþmêrM and personnel 1n.-11d from lOoCåIioo to be provided by Peficán Hilt 018. Gas. ILIAMNA DRILLING PROCEDURE REV lOOCT.doc Pelican Hill Oil and Gas, Inc. Page 40 10/10/03 ILIAMNA DRILLING PROCEDURE REV Pelican Hill Oil and Gas, Inc. R..3 A.1o.w temperature relardåt uød in à wide .range o~ slUrry form..daIiM$ toe:'dèind the stutty 1JIj¡lck.ening tin'tré . Sodium MelâSillicate An èxter~er u::g,ed 1ø produœ an economleaJ, low density cement slUrry. 100CT.doc Page 41 10/10/03 Potassium Cf!1loridif! Agf'añUfar salll usèdki reOOCé cliãV$wclling œU$éd by wá,1er-bilí&ê cementing 'iluide P·olauium Chloride Agranuliat $ålt Ij~èd to reduce cla~ 6Wèllîng cau&t!id by wtl,ter-ba1õe stiimulatii:lnltüid$. Mcs..4 A. wrbldentRow spacer system that ;prevet1t& water water-Voféts úiíè c;d;inQ to incréasê bonding. and oil-base mud and cement contamination and Ikþidthì!lt œCrêi:U¡èS fbslmll1g F·P-6L A. clear FL-&2 A patented dry blend of water sòkJbkI polymef& that ate fOfmotated to control the 10/IiiS of ftoid during ~menting opêraüons. A _ê,fsant ànd bondmg additive ate prøportiol'1éd to deliver consistent pérlornmnce and contrôlftuld IOâS ihþnltlaty and squee:te cementingapplK;á'lions at low 10 möderale n sbrief> dOfi~g tnìlC:îrl!9. Clns G Ce«Mnt Intendéd b iU&E!' i!iìS is basK; celtlêflf tom sur1'Doè tó 8000 ft a$ ltIanufadUfE!(.L 01 (;00 be U$Ðd 1NÎIth accek!ræor¡ and retardms to ¢Over Of 'oNide Imge of 'Nelt depths átld ,*mperatutes Calc'wm Chloridè A þOWdéred, naked or péiletized material used tô deae;d;e thickenîng time and inCfeáSe the ratt! of strength deV8lOþméfJt. C042 A pøtënté1d, fteé~lowing, retnêd\Îal Cémênting. Ekmtonile Commonly wtttér ca.ëd~, it Í$, á clay maÍétial used ãs a cement extendér and toccmtl'oi exceníve ffêØ Wâter. solUble potymer that is an effiëten,t and effêdîv. diSp~nt for ptimar\, ëìnd Barite A. natuf'8l1y' oéCufitl,g mlnlllfa~ (Barwm Sutf81è). Et ÍS!Vìí'ildieJIV Ul&êda$ â ~ghlJng thtí!llÌal ÌI1I CGimènt and oœàsionatly in œm¡éNf;lurriu, It can yJe,ld ì!II 8lurryœnæty in œœssof 191bis1gat ~aoora DA.- An ncm-œmpaœdslbfumelhM produces hlgih èornpl~'èa1fèf'lgth, low dmaily Cènmm 8luwie, Whh::h plfeVèf'lt annular gas ml1Jra1km by reducing sLUrry p.me:ebilitJ. It can be uud In the low 10 high tempemlUfê rang.. BA..10 Iß'lPt'õvu, cement bending md actliìs ÈÍ maim ftow controlagmt. and dM6d skirrl. Dt ,modlllfate tèmplllfalUf'é*'. It Cí!ln bit tilsed lin Igfttwêight, _ndard ASA..a01 Additive used to reduce or élirinm tü~r and Iff/OIing in Cí!!mént skim... PROnUCT ~Rr.'RIPTlONS e e e e CONDITIONS iu¿j·· .;:J . ?! . -"""."""-"'",--,,--,.,,'-""'.- . .. .................. ... 8J Servicast ptft'orml1nœ of urvices M'íd sa. of matldals iaøptèl.sly ctmdilloMd upon the applicablity of thä Téfm& and Qaadì:ÎOAtl Cõftlainäd In thä current BJ ..,dcn Price Book. Thä TIffñ8, end CotvJItiom¡ include, among other thl.., an indemnity in favor of BJ Sètvl\ces tom CUstòmet for damage to me 'well bore, ifaørvol, damage, Ion of the hole, blowouts: and lose of conlrol of the well, even if CMlsed by the Mgligence or öltier fauft of BJ GenAe.. Thä Tem'iêand Conditions 11813 Imlt the W'8ff8n6es pt(tí¡llìded bylhe BJSêrvlces and the remedlin tõ whidh CustOß'Mír may be enHed inh event of 8 breilëf1 01 'WIIfranty' by BJSêr\lfœs. for these fnsooS, Wé SIrOl'IÐly recommand thai you c8fliMly revlfilW8 copy onhe Terms and Co/'tdiìliorrs. If yea do nOC have a copy of the BJ Services Price Book, you éãö Vièw1hè· Tèl'fltl àö.d Ccmdltion& 00 BJSèfV'ÎCèS Wèb Site, WWW.*è"~ðM.By ~tlng that BJ Servlcø. ¡perf01rm ....lêrvk:éS dèsctib«lllerefn, CuistoIMr acknowleda_ that Iìldí Tèi'mš.áIftd Cöndiliõn. aM appllcäblè to"" HfYices. Futlhêr, by NqüM.tiJifl thè s.rviœs~ Customèr warrants that lis ~ on lhê wel location orõlher Hrvice sb will beftlly .f"¡(wlad to acknowledgè weh Termsn Condhkms by éXì!iCuting ill Field Receipt or othär document presented by BJStmtice& œnlaftlng such Term& and Conditiofts. In Ihä Þêhtthat CUstomêt and BJ Stmticu have èDCübId a MaMer SenticesAgreement f:iOV8rihg, the wo... 10 bè pe.fGj1t1èd, such MiHterSefllÎCes Agttlèrnent shaHgO'ltêm in placè of the TermsllAd Conditions. If you are ÍI1tMU1ed in êR1aring into Mastär Service" Alf8øment with BJ Seryice.., plMH·CQft1ad us "'rough 1M "'Co BJ'" button on the 8J Sänrices Web... BJ SERVICES CONTACT INFORMATION BJ Services Company Kenai District - Operations Supervisor · Ed Post - 24-hour dispatch (907) 776-4084 BJ Services Company Kenai District - Service SU1>ervisors · Marshall Brown · Robert Moore · Smokey Poage · David Wallingford Regards, Jay J. Jay Garner BJ Services Company, USA Alaska City Sales Manager, Pacific Region (907) 349-6518 Office (907) 229-6536 Mobile email: jgamer@bjservices.com ILIAMNA DRILLING PROCEDURE REV 100CT.doc Pelican Hill Oil and Gas, Inc. Page 42 10/1 0/03 LOCA TION LAYOUT FOOTPRINT DRAWING RIG LAYOUT DURING DRILLING BELOW SURFACE CASING --.- I· I· Pill Pits 40'-0" SuctionPits -~-_...._---_.- - ...-. - ---.155' -0"---·-- -I Solids Control -1 r---------...... -.4:~··----·1 I~ Derrick l I...:~ & i Derrick Shaker & f A.f/f l Degasser Cones Gas ,/ , .. . ;.;. 7··;·'-;-'·"·'~':-'-·;:-~:; 'f;. I .;--;:,-~ / 8' Atm¡..4enc Vent .~ .~.' . . ll~TO,ØOke~.n~oId ~. _22'-211116"i- ,.. I ".:' ) .'~ -, ~', .:: ~upt~¡~ . .. ..._.. ·W'·- ~~...rf ø 'Ô.å' Tesco -.-- -- -...........-... --. - - ...... -. ..,,;¿-, . '- ~,~w:/!Þ Power 8'-0" L._:.._,~:_:...:,_:.:__:..:-,..¡~~t:...:,~_:~-,--,_._~::.....,..::",l:I,-,-.~:;::.. V ~ Unit.-l j(.~:::: ·~~W·:;f!'i l' 50'..0" n;"'.'· .,,,,:...,,~.: L;,:--- -.'\. , 'i ".. .' 1 X '¡: .~g Floor 1"·;1 .... '1,,/ ( , ",:_ .. .. .. .: ... ":' .~ . ~: .',:::' :.: : '.1: e --.- t-8'-O"--1 I . ___....__..... _..._......._.__.._._n_n._'__..,._....___ ___._.. _. ....n ..'.. :....: _ ..:.&.;.~. :___.'..:.-.. :'_.":':':-:-=-":'¡':'.-':"-_-='!..-.~':":....! ~:.....:..a....-:_':"";"':"":'.:...:__ .. ..... . 3x~:' ", ::; t:,,,,~ '.. -: '.0 '[3x4 ..: ·1 :. ''urr~. I :: .. ." ..... -. ..... ... --.- 1-8' -O·--+i ! I I I I Tool I House 7'1:-0" 33'-6" Oíesel Tank 20'-0" I I ! , I _L I ~- ~ -2- D m BUNt<ER FOR DRlIMS ~, GASaJNE TANK '-------./ -2- '-------./ I· '1 '.- .."1· :.... ~....~.:.." "'. .... '. ~~ -9'-6"- ..---16'-0"-----1 ---16'-('1'-- Generator 2 I I L~J~ Generator 1 -SO'-2" ILIAMNA DRILLING PROCEDURE REV lOOCT.doc Pelican Hill Oil and Gas, Inc. Page 43 .. . ...., CatWalk '. ..: I::·: ~ .. . . -.-- .. '" ~ ~ to 1_-------.- ___.,__~,_.L____________. 16'-0" H20 B Tank ~ 20'-0" Pipe Racks --,._---~.._.,----..__. comp~S$or --'T 8'-0" ~ ----1 e . -.- --- -"-------.-.-- 30'-0" \----~I -2- -1 TIn" ~ "'''''''''"... ':>_::'-'-'"~.,,, .-, "",'" "",,": ...'.--- ...""'" .. .. .1Jt-.. :: :;:"Hji,o,' .~!$_:'; -:-~-."-<_:--.:_ -_::-;': '1n~" - - 'n, :'.. .. -:'- __ _ ,_ : /;<.. __:_~;'; <.~' :,,:., _ :",:. .:._'_"".',~:,- '-'o\: .~1,,~,-__,--:~, 4 .'. . .!œ ~'''WN;;'''.W",~·. -;. -;--/::-'<->--'-"_::',Miilbiaae;:AI~;;; 10/10/03 RIG LAYOUT WITH DIVERTER LINE IN PLACE Solids 20'-0")1 . t1!)% rrictPe rrick DegaS~aker & '.'O'o~~'"'~='oO' h'o'"o=·~oO~_~" """dT~'oo"''''~o~''''-''''.~'.'~"'''.;: ,. ",,~,..~,,~~,O":'::-'.~-r- ,."'~-~' , r II U I I' L;.;:'-;~::;.,"': ! c' I ,..,.... ,..' '.: ~. eP' . CI,r;~ f~l d~ ¡~~I~]l I H __!If' -.c, .- --- - ,lIIJ ".. f·· F \fffip ~_: ,I ~..', -;.: ." . I IT'] ill I 1;-· , i· l~~! ¡!:¡¡':"·:::i::~:;-:~;;~';~:~~:,o:; ~;iiU:!~ :;¡ ,Ii '\.1,: ¡¡ rr:¡ ¡:.:,,:~~:;~~-;=;¡ ¡¡:i; i.i;: i!' ¡!', ¡::::::': ;~~: ~:: ~;:¡·ii;':+~ H ~ ~. H,Ig-:~' - ~ 00 I ,j]tl~~; ,__ - IIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIJIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIII~ 11I1I1111111111 11111ftlllllllllll~ . ILIAMNA DRILLING PROCEDURE REV 100CT.doc Pelican Hill Oil and Gas, Inc. Page 44 / . . / 17'-3 7/8" 10/10/03 I Tesco Power 25'-œJnit Cat Walk e . 4'-0" - . e e e ... SPACE OUT AND DIMENSIONS OF DIVERTER WITH TWO 13--318" SPOOLS ... ... a. ... to RKBtoTop Pollution Pan 16 Inches ~ Inches RKBto Rig MAT 150 Inches from RKB to Ground level with Two 5" MAts ... ... ... RKBto Top of Hydril 54 Inches ... ... ... Height Top of o Bottom Of Item o 0 Rotary table .. ... ... .. 8 8 o 8 bushing 8 16 SPACE 38 16 54 Bell Nipple ... RKBto RKB to ~ Top of 12" Diverter Top of Top of Line 24" SUB DSAF 120.4375 BASE 93.75 Inches 116" Inches Inches RKBto RKBto top of Bottom of 39.75 54 93.75 HYDRll DiverterDrì 12" lling Spool Diverter RKBto 98.1875 Line top of 5" 4.4375 93.75 98.1875 DSAF .. Inches 132.4375 Sub Inches beam 111 Inches ---.- RKBto I Top of 131 -.------I 5/8" SLIP + lOCK I Csg ... Head 147.1875 Inches 22.25 98.1875 120.4375 Top of 12" Diverter Line ... ... 12 120.4375 132.4375 Bottom of 12" Diverter Line -------- RKB to 13- 3/8" Cutoff 165.6875 Inches 14.75 132.4375 147.1875 Top ofCsg Head RKB to bottom of Cellar 222 .incl:as- 18.5 1471875 165.6875 13-3/8" Casing Cut + ... 563125 165.6875 222 Bottom of Cellar 45 46 140 16 1 r Ton of Rotarv nrifJ F100r 3-3/8" 54.5#, K-55, Buttress Casing Set at ... 80 feet RKB v .. t e e A æ . . m þI ITEM Dimensions CELLAR TZ'Diameter RIG SUB 70" Wide by 7'Z' Long 13-518" 5M Flange 26.5" Diameter 11" 5M Outlet Flange on Diverter TEE 23" 11" 5M by 150 RF XO 11" Long by 19" RF Flange 00 Series 150 RF Flange 00 19" 47 e e SPACEOUT OF SURFACE CASING NIPPLE UP WITH SPACER SPOOL FOR TBH HEAD a a .. .& .& .& a a .& .& HeIght Top of Bottom Of Item 0 0 o Rotary 1able 8 0 8 bushing 8 8 16 SPACE RKiITõ Top of HydriI 54 .I/l!t§L 38 16 54 Bel Nipple .., 'RKB'iiï Top of Rams 93.75 Inches -. 39.75 54 93_75 Hyåil 'Ri<ã'iO top of Driing Spool 123_125 Inches RKiITõ Top of Spacer Spool .. 140.5 Inches 15õïïiCiieS from RKB to GroIn! Level wtth Two 5" MAts · RKB to Bottom of Spacer . SpooI168 Inches 29.375 93.75 123.125 Rams 17_375 123.1 140.5 Cross . ~ bottom of 9 518" Csg · Head 185.5 Inches 27.5 140.5 168 SPACER RKBto 13-318" cutoff 191_5 . Inches 17.5 168 185.511"CsgHead .- RKB to bottom of Celar 222 Inches 6 185.5 191.5 13-3I8"CUloff ... 30.5 191_5 222 Celar Bottom 48 Top of Rotary Table RKB = 12.1' = 145 INCHES AOOVE Ground Level with 5" of Matting, 150" with 10" Mats .n. A SUB BASE A v À ... Kin Une Side CHOKE LINE SIDE v A GROUND LEVEL ELEVATION 15 FEET IMSL 'W 't.f 49 e SPACE OUT OF BOPE WITH TBG SPOOL IN PLACE .. .. ~ Top of Hydril 54 Inches --.- 1140 Inches RKB to Rig MAT " .. .. .. RKB to Topol Rams 93.75 Inches .. RKB to Top 01 TBG Spool 143.5625 Inches RKB to top 01 Drilling Spool 123.125 Inches .- ~ Topol DSAF 1405 Inches -. .. .. RKB to Top 019· 518" Csg Spool 165.0625 Inches " RKB to bottom of 9- 518" Csg Head 182.5625 Inches. With 4" 01 9· 5/8" Casing inside head " RKB to 13· 3/8" Cutoff 188.5625 " Inches .. .. .. 150 Inches from RKB to Ground level with TwoS" MAts .. RKB to bottom 01 Cellar 222 inches " e .. Height Top 01 Bottom Of Item o 0 0 Rotary table 8 8 o 8 8 bushing 16 SPACE 38 16 54 Bell Nipple 39.75 54 93.75 Hydril 29.375 93.75 123.125 Rams 17.375 123.1 140.5 Cross 3.0625 140.5 143.5625 DSAF 21.5 143.6 166.0625 Tbg Spool 17.5 166.1 182.5625 11"Csg Head -r 6 182.6 188.562513-3/8"Cutoff .. 33.438 188.6 222 Cellar Bottom 50 Top of Rotary Table RKB :: 12.1' :: 145 INCHES ABOVE Ground level with 5" of Matting A Á 'tf '" ,. SID" 'Iff v 2-1/16" s..I Valve 11" 3M by 9-5/8" 3m SOW VRPluj:¡ 11"3Mwellhead Height 17.5" . 136.5" Gap from bottom of I 13-3/8" to bottom of Cellar . Hydril Weight 5300 #'s HeIght 39-314" Closing Volume 7.43 Gallons Studs 1-3/8" by 9-112" 16 Studs and Nuts Ring Gasket R53 Studs Required 16 Stud SiZe 1-318" by 9-1 I'Z' Ring Groove R-53 LWS Height 29-3/8" LWS Weight 5080 #3 Closing Volume 1.74 Gallons Opening Volume 1.45 Gallons Closing Volume 1.74 Gallons Opening Volume 1.45 Gallons Mud Cross Height 17-318" Ring Grooves R-53 - ~"......~ ¡¡;:::::,:..:; .01 '."; ".'. ~ t.' j ,- .~..." ,~-")",,,- e f¡iò , ~h f, ,,#I ILîJl~'-·r.~".'1>: r ty*..~.~~. , .' ;1,.., ,... . j, L ;a ~ · ^::~'Iì ~.-~~ I - -~. f ITEM SIZE Ring Gaskets # of Bolts Bolt Size & Length A. 3-118" 5M HeR Valve on Choke Line R35 8 Per Flange 1-1/8" by 7-1/4" B. 3-118" 5M Manual Plug valve on Choke Line R35 8 per Flange 1-1/8" by 7-1/4" C. DSAF 3-118" 3M by 3-118" 5M R31 and R35 8 Studs per side 7/8" by 8" & 1-1/8" by 7-114" D. DSAF 3-118" 3M by 2-1/16" 5M R31 and R35 8 Studs per side 7/8" by 6" both sides E. 2-1/18" 5M Manual Plug Valve on Kill line R24 8 per Flange 7/6" by 6" F. 2-1/18" 5M Manual Plug Valve on Kill line R24 6 per Flange 7/8" by 6" t $pill PtevetdiGn P.IIn SIT by q by 'Z' J & ~irlt::'- r: -- F-·-iit ---. _1 p¡p¡;NïPP8. HeiI WiIIt Ftered I ~'~!._.".... OJ II'I8/aH38 ..... .... :æinche&,,~~?,I1 ., ' ,"!", ..- . . ~ <' \" :¡" v' ilK>he$ ·1~. ~.~I.' OIIUtiOnparr;;""¡""'''"'!:'f''';P!,\t,\~:,\.,-:. r =Nipple. '1' FIll up line, . I~~:::'..d~.:'. ~I~. in8~·.I. . ..~~..1·~'5a'~DlIFi1!:.Ø~~_I~' . . "', '. ' \ nuii"~~.IIr~B,~ifAi~;·i~';i;]~;~1"!~t~:~~$.;1~~ 12" horn. bOttom 0/ Fillup line to.top 01' Flanj¡e . 12" O,? ., . . .. . WID· . -+ '. R~ Rin/l'ö_ -;::J . $þUI!Iii!_-P~:tiY%7< 1~{;1'.1!1¡·~~;~'k'~f'~""····1.······ ....... ... '.',..... "..', ..'.' , ."."'. .,..... ,., ,..,. .'.'.,.,'. .;~;~~·t ,;~.::: ·:1: :..::.': ;:.:.:.::'~~\~~:::.::' 'j,.,~..: .~. :.» <" . P·· ..........................:... ... .::.;>.:..:.. .,.... ' 52 ITEM DESCRIPTION 53 r.1 e ~h "....ç: <- ~. - ;" ,'.,,1' '')Þ'., -r'~-'. : :-f ß ¿' . Iß;~~., ..'...,.~'..."'''''''"'.... r".'.'."'" , .....:r~--- " - '." , -.-....; ,.;..:.'.......'.. . ..-->:,-' fl ",' ".,. .. [J 54 r.1 e e e ACCUMULATOR VOLUME REQUIREMENTS AND BELL NIPPLE DESIGN BELL NIPPLE DRAWING FOR USE ON ALL THREE NIPPLE UPS ACCUMULATOR VOLUMES REQUIRED, TEST PROCEDURE AND BELL NIPPLE DESIGN ITEM Annular Ram Ram HeR Vol to Open Vol to Close Total o 7.43 7.43 1.45 1.74 3.19 1.45 1.74 3.19 0.5 0.5 1 14.81 150% 11.145 4.785 4.785 1.5 22.215 Acceptable volume of usable accumulator fluid is equal to 22.2 Gallons. The Accumulator should still have an acceptable pressure of 1500 psi remaining. Accumulator test procedure. Fully charge bottles to 3000 psi and shut off pumps. Shut off air supply and electrics to the accumulator Close annular and open same. Close Annular again. Close and open each ram and close each ram again. Open and close HeR and reopen again. Measure accumulator pressure and confirm same is more than 1500 psi. If accumulator pressure is less than 1500 psi, Isolate and check each bottle for correct Precharge. Each bottle should be precharged to 1000 psi with nitrogen prior to filling with hydraulic oil. BELL NIPPLE DRAWING FOR USE ON ALL THREE NIPPLE UPS ___L ='38 ;,¡.;.. ".' ..... . r=~ frani '. of11OMine to top of j 1--- :¿,j.~ M'·'-"':'{I'I;~.: -u.·...l'lþilln. . ...-- ,. -- . ¡ ---- . I .~~ it·'- :ø.... .... ..... .-.....~. 1'1'· NI~. w/th'1ô(J2 CotJpIJI'!O.. ·1 """'I.- ':ÇF~' :.' ··"10" ô9' If 0'" une Pipe QutIet.QIA fOr .ftÐ'Mirielfbary:~ . .. . " _.$Q:~t~~ '.. ,~. .'.>.:,.~,'.:.. . ... . '. ,. :....'.,.,.. ;'::. '" ..' '1' .. . - ... .'''. ,.. n: , .~~..:( ~"~À''''· ' Gt,eerJtIÇe. ~itted ..8'Mf.(ìØOß!!!ÇtiØl't-for. Ô" FIøwI!œ 2' fTò!n bQttøni· ofFill\¡Ip lnàtØtq).of.Flqe ., .,. J~.qo..i ~ -"'"-.'".,~ '.'''; ..."" .".' .... ..':::: .~.~ ,,;. '". ':,:;f~l#g;* ~_.:..- ., -"-. ··1 ... ,. .,.. ..1.1.~JI"'. .'.. ... *1~'¡'.f>Jlh' . ""~.9,.""""¡dií~:"\"'!l!íd:'J"'\'i"""."¡¡":,,,,,,,J . I...·;r·\_..~:ì".-....<'.:.... :....1+ ~~~iii~~ ~Rfng Øe~ ~ ~~'~!!f;j;,~!'ii1'fj,_mj¡~¥~Ji.,?\..""",,,@íl Spill Prevé~'¡tí.îíl30" by 42" bï ' s "UP ef¡t.. .~. .Tf~ b '42" b2' pl. .QI\I; ~~I~t:',,,,rl~· Y I' "'¡';';¡;'\4~~~'''' . .~ '.. .y ~1'~4:~:. " ,. ,¡ ....,": .,'".' 'i J- ILIAMNA DRll-LING PROCEDURE REV lOOCT.doc Pelican Hill Oil and Gas, Inc. Page 55 10/10/03 fJ) ..J W W c ..... ..... I!( ~ 5 Z ~ W ..J f2 4 ~ o S2 AD KICK TOLERANCE CHAR 8.0 10 9.0 10.0 MUD WEIGHT 9 IUAMNA # 1 SWAB KICK TOLERANCE VERSUS MUD WEIGHT VARIOUS FG"S WITH CASING SHOES AT 550 8 7 6 3 2 1 o ILIAMNA DRILLING PROCEDURE REV lOOCT.doc Pelican Hill Oil and Gas, mc. Page 56 11.0 .60 FG "" 11.5 .65 FG "" 12.5 -+- .70 FG "" 13.5 FG .728 .75 FG "" 14.4 .8 FG = 15.4 10/10/03 P SSURE KICK TOLERANCE C o 500 1000 1500 2000 PSI 2500 3000 3500 4000 °1 bSVMÆê&WX11.5# MUD HYDROSTATIC 9-5/8" @ 5 1000 2000 - -10.5# MUD HYDROSTATIC - ~OIIMUD HYDROSTATIC ~ASINGSETI1NG 3000 illC'.ffiSW'MAXlM1JM KWM KICK TOLERANCE IN PPG WITH 11.5# MUD ~IMUM KWM KICK TOLERANCEINPPG WITH 11# MUD ~AXIMUM KWM KICK TOLERANCE IN PPG WITH 10.5# MUD qx¡¡¡¡4f1\'tIWlÆ'MAXIMUM KWM KICK TOLERANCE INPPG WITH 1011 MUD 4000 5000 1 6000 10.0 10.5 11.0 11.5 12.0 12.5 13.0 13.5 14.0 Maximum KWM in ll.JAMNA DRILLING PROCEDURE REV 100CT.doc Pelican Hill Oil and Gas, Inc. Page 57 10110/03 IUAMNA #- 1 PROPOSED WEll BORE SCHEMATIC TOP OF CEMENT ASSUMED@ 16 FEET RKB TD 5500 FEET Hole Size 14-3/4" from 14' to 80' 13-318".54.5#. K-55. Butt Casing at 80' RKB 13-318"ID 12.51" from 12- to 50' Hole Size 12-1/4" from 80' to 550'. Hole Vo1ume 76 BBlS 30 BBlS Cement Required 46 BBlS 255.6 Cubic Feet 9-518". 32.3#, K-55. STC at 550' RKB 9-518"ID 8.921" from 12' to 550' "X" Nipple @ 4900' 5-112" by 2-718" PACKER @ 5000' 2-7/8", 6.5#. K-55. EUE 8 Rd Tublng@ 5200' Hole SIze 7.875" From 550' to 5500' Hole Volume 339 BBlS Annular Vol 178 BBlS Cement Required 222 BBlS 1245 Cubic Feet 5-112".15#, K-55. l TC MAV@ 5500' RKB HOLE SIZE AND CASING AND TUBING ANNULUS CALCULATIONS Total Hole Cased Feet of Feet of Volume Csg Casing Casing Hate Casing Depth of Open Hole Csgln Csgln Cased & DlsplFt Csg Size In Welghl Size In lOin Shoe In Hole Vol Volume Open Cased Open Hole 10 In Olspl Inches InPPF Inches Inch.. Foet In BblsIfIln_ Hole Hole Bbls bbIsIfI !ibis Ann Vol In Bbl. fromTO to CeUar Casing Cem"'" Capacjty Vol Reqd from RKB In Exc... % bbls Bbls 13.375 54.5 14.75 12.615 80 0.211 0.000 54 13.525 0.174 11.1216 2.404 50 3.606 12.367 NOTE Calculations based on top of cement at bottom of callar. 9.625 32.3 12.25 9.001 550 0.146 0.155 470 54 78.406 0.090 48.0552 30.351 50 45.526 43.285 NOTE: Calculations based on top of cement at 16 feet RKB. 5.5 15 7.875 4.44 5500 0.060 0.079 4950 534 340.224 0.029 151.147 179.078 NOTE: Celculatlons besed on top of cement at16 feet RKB TUBING CALCULATIONS FOR ANNULUS VOLUMES AND CAPACITIES Casing Ann 1/01 Annular Depth of 1/01 Sot_o Foot of Foot of I/olume to End of balow Tbg and Tubing Tubing End of Tubing Tbg In Casing In Below Abovo Tubing In In Feet SPF BPF Pack... Packor !ibIs Tubing Tubing Hole Tubing Size In Wolght Size In 10 In Inchos In PPF Inches Inches Tubing TBG Olspl to Tubing DlSpII't Pack... Capacity In BPF In !ibis In BPF 2.675 6.5 N/A 5200 0.019 2.441 0.011 200 5000 57.827 0.006 40.1461 Page 58 25 223.847 105.324 Tubing Tubing Capacity Capacjty to Packer to EOT FUll Circulation Volume 10 EOT In Bbls 0.006 28.940 30.098 87.925 e e PROPOSED DAYS VERSUS DEPTH CURVE PEUCAN HILL OIL AND GAS, INC. lIIamna # 1 Anticipated Days Versus Depth -10 -5 0 5 10 15 20 o . Davs, ""1"" ,,', ...+_-!-_+.+n_.+-+_+.+-._ "'+-+--+-"1'--- -'+--113-318" @80Ftj·---i·--+-··im-..-+-+-+.+--- ::: :~:::: ¡::::r-: ::;:::: . :::~::: :¡::::r-:: :;:::: ::::~:::: ¡ ::::r-::: i:::::::: i:::: ¡:: ::;:::;: :::!:::~:: ::¡::::r- :::;: ::: ::::~::::¡ ::::r- :::i:::: IIIjEIEj:tHIj::T¡tj'~~IEH~IrFj:: 1000 I . 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F " " " ", 1 1 , L , I' '" 1 I", " 1 t '" 1 _ ...._. _ _. _ __ _I- __ ~ ,,___~ __~ _....1__ _ _...__ _I_~ __" _ _ _ _ __ _ _-'__~_._~ __._ __ _..._ ___ __ --....1--- _ ...____1_ _~ _,,_ ___ _ ___ _ _ _ _... __ __1_ ___.1_ _ __ __ _ ~....I___ _...____'- ___..._ ___ " ". 1 1 , " '" t "," I , 1 , t ,I r' ,¡" ,t r I) 1 " t '~___I__ _ ~.. _ ~ __ ___ _....I. _ _ _.. _ _ _L. _ ~~ ..~___ _ __ _-'__ _ _.. ___ _1_ _ __.1__ _ _ _ +_ + -'_ __ _.. _ _ _ _1_ _ _ _... __ __ __ __ .___...__ __,_ _ _ _,,_ ___ __ __ ....1____. ~ _~ ~I_ _ __..._ ___ " 1 " 1 L " 1 1 ," 1 1 1 , , , , I' 1 1 I, 1 t '" 1 " 1 I, 1 , - ~-~ ;----f- - --;-- - -;- - - -- --:~ -- -f -- --;----;-- -- - - - - -;- ---; --- -;----; -- -- ----;- -- -f- - - -:- ---:---- ----:--~ f- - --¡- - --1--- - -- --:~ - - - f - - --;- - -- :---- + --- ~_.- - ~ ----:- ---~---- -----:.-- -~----:-_.- ~- -- - -- - -~----¡----:-- --~- -- - -- ---:--- - ¡ -- --:~---~ - --- - ----:- -- ¡ --- -:- --~~~ --- -- ---:----~----:- -- - ~- --- 1 , I' . 1 " " " 1 t t' 'I" " 1 _ ___~--- _ ~__ _ _:-~__ ~ _~__ ____~--u~- ___;__ ._~- ___ ____ ~----~-- __:----~-- _ _ .___-:_ __ _~__ __:~U ~ ~_ ___ _ u_-:_ ._~u- _;__ __~---- ____~---- ~~ _ __:--- _ ~____ 1 , I! ,. 1 1 1 1 I' " 1 1 "" "" -----:---- ~-- --;-- ~ -~- --- -- - - -:- - -- ~-- - -:----~ ---- -~--~:-- - -~ --- -;-- --1---- ,--- ~- ---~- ---;- ~--~---- -----:-- -~----;----~---~ -- ---:- - - -~- - --:- --- ~- --- : : ;: :::: :::' :::; :::: ::;: , 1 " I'" '" 1 "" I, I' 1 1 1 1 . 1 I 1 I' 1 1 "" " " " " 1 1 , I _ -- _ -{- _ - - ~ - - - -:-- _ _ 'I - - - - - - - - -:- - - - ~ - - --:- - -- ~- - - - - - - -..¡- - - - ~ - - - -;- - - -.¡ - - - - . - - - -:- - --f -- - -:- - - - ~ - - - - - - - - -:-- - 1_ - - -;- --- ~ - - - - .- -- -:- - - - ~ - -- -;- - - -.¡- --- 1 , , 1 , 1 " , 1 1 1 1 " , I 1 "" "- -- ~- -- ~ t - - --:- - - - ~ ~ - - - . - - --:- - -- t - - - ~:- - -- -1 - - -- - - - - -:- -- - t - -- -:- - -- ~ - - -- - - - - ~- ~ ~ - + -- --;- - - -.¡ - - - - . - - --:- - - ~ - ~ --:- - - - ~ - - - - - ~ - ~ -;-. - - t - - - -:- - - --1- - -. 1 1 I' ", 1 I' I' '" 1 1 " "" - - - - ~- - - - + - - - -;- - - - ~ ---- -- - - -:- - - - + - - ~ -:- - - - -1 - - - - - - -- -:-- - -t -- - -:-- ---1 - - - - - -- - ~- - - - t - - - -:~ - - -.¡ -. - - . - -- -:- -- -t - - -:-- - - -1- -- - -- -- -:- - -- + - - - -:- - - --I ~ -.- , , " ", 1 "" " 1 1 " I' 'I' 1 _ _ _ _ _:_ _ _ _ + _ _ _ -:_ _ _ _ ~ _ -- _ -- _ _ ~- - - - + - _ _ -:- _ _ - ~- -- - -- _ - -;-- - - + - - - -:~ - ~ - -I - - - - - --- ~- - - - + - - - -;- - - -1 ~ - w - . - -- -;---- + - . - -:- --- ~ - - - - -- -- -:- - - - + - - - -:- - -- ~ - --- . 1 " 1 1 " ." 1 I", '" 1 "" - - - - i- - - -f - - - -:- ~ - - ì - - - - - - - - -;- - - - f - - - -;- ---1- - - - - - - - -:- - - - r - -- w:- - - - ~ - - - - . - - - i- - - - + - - - -:- - - -7-- - - . - - - -:-- - - f - . -:- - - - ì - - - - . - ~ - -:- - - - + -- - -:- --- ~- - -- 1 , " ". 1 " " . 1 " "" . 1 1 1 - - - - ~- - - - f- - - -:- - - -.¡ ---- . - -- -:- -- - f- -- -;- - - - ~ - - - - -- - --:-- -- + - - - -:-- ~ - {- - - - . - ---:- - -.- + - - - -;- -- - ì -- ~ - . - -- -:-- - -+ -- -;- - - - +- -- - .- -- -{- - - -+ - - - -:-- -- {- - -- , 1 " "" ,,, 1 " I' I'" "" - - -- i- - - - + - - - -:- -- ~ {- - - - - - - - i- - - - ~ - - - -:- - - - {- - -- - - -- i- - ~ -} - - ~ -;- - - - ~ --- - . - - - i- ~ --~ - - - -;- - - - {- - - - - - - - i-- - - r - -- '- -- - {- - -. .- - --:- - - - r ~ -- ~:- -- - i- - - ~ 1 , " "" "I' 1'., " 1 "" - - -- i- -- - r - ~ - -;- -- -.;- - - - - - - - -;- - - ~ r - - - -;- --- i - - - - - - - - -:- ---} -- - -:- - - - i - - - - - - - -.,- - - -} - - - -;- -- - i - - - - - - -- -:- - - -} --- - - - - - {-- - - -- - -..;- - --} - - - -:- - - -; ---- 1 , I' ," 1 1 1 " '" 1 " , 1 1 , 1 - - - ~- - - - r - - - ~:- - - - ~ -- - - - - - - -:- - - -} - - - -;- - - - ~ - - - - - -- ~--- - r - - - -;- - - - ~ - - - - . - - - ~- - - - ~ - - - -:- - - - ~ - - ~ - - - - - ~-- - - r - - - -:--- - -{ - - - - - --..;- - ~ - ~ - - - ~:- - -- ~ - - -- , 1 . 1 I 1 I' '1. 1 I'" '" 1 "" : ; :: :::: :::; ;::: :::: :::: 1 , " "" ,I " '" 1 'I I' ", 1 , , " ,', 1 1 I " 1 1 1 1 "" "" _ _ ~_..,_ __ _ T _ _ _ _,_ _ _ _.. - - _ w . _ _ _..,_ _ W _ T _ _ _ _,--_ _ _, _ _ _ _ . _ _ _,_ - - - T - - _ _,_ _ --.. - - - - - -- -.,- - - - T - ~ - -,- - - -.. - - - - - - - -.,- - - ~ T -- - -,- - --'.. - - -- --..,- - - - T- - - ~r - ~ - -, - - w_ 1 . I' I' 1 1 I' I 1 " I' 1 1 ,. "" - - - - ~- - - - ~ - -- -:- - ~ - ~ - - - - . - - - ~-- - - ~ - - - -:- - -- ~ - - - - . -- - ~-- - - ~ - - - -:.. - - - ~ -- - - - - - - ~- - - - ~ - - - -:- -- - ~- - - - . - - ~ ~- - - - ~ - - --:-- - ~ - - - - - ~ - - ~- - -- ~ - - - ~;- - -- ~- --- ::::~._u ¡·-·+···i···· -···+-··¡·"+--·i·--· -... +"'i""1::::~:::: .:::~::::;::::~:::~:::: ::::~::::;::::1::::;\ ::::~::::;::::~:::~:::: uul -ANTICIPATED DAYS VERSUS DEPTH l~__+m__+u:m+__+m _w~___+.+.+n : : : : , 1 " " " "" "" I, " I 1 1 1 ::::1::::1::T::C: ::::r::1:::r::c: ::::r::1:::r::r:: ::::r::¡:::r::c: ::::J::::1:::r::l5-112" @5500FtU:::: : ~::;::::¡::: :¡:::: j:::: :::: ;:::: ¡::: :\:::: 1:::: ::::;:: ::¡::::~::: j:::: ::: :i:::: ¡::::~::: j:::: .:: :;:::: ¡::: :;:::: j~:: l:: ;::::;::: :~:::j:::: . , " , - - _ -_ -.,_ - - - T- - - _,_ - ~ - T_ - - - - - - -...- ~ , , " 1 -.----,----..- ------....----.- 4000 6000 ILIAMNA DRILLING PROCEDURE REV 100CT.doc Pelican Hill Oil and Gas, Inc. Page 59 10/10/03 POSED COMPLETION SCHEMA ILIAMNA DRILLING PROCEDURE REV lOOCT.doc Pelican Hill Oil and Gas, Inc. Page 60 10/10/03 · e PROPOSED XMAS TREE AND WELLHEAD EQUIPMENT SPECIFICS ,Y' ~ .", C!I ...' .."... ·~as CI 1I-11t' "'I 14.. - 16 .... AS 17J111' r- .... " ~. "J iI!-711r all Till -~~.IJI~ ~HIr ØD CS& II.!. - ME IfIIIIIIIL. ..I, .... ....... - ,.YIIID ...., ...._ It ... .. AlW.r s.: a: F'Œ ENGlNŒRINQ ACAD 9-518 X 5-112 X 2-718 aD" 5M NIP AllY D~-- - ... - .¡ 1>11 . ' 4",'''~ .... ,'1.,"'''1',,11: .'.. "."'1' ,.r.. .. II NO. "':; - - m'~,:·:'"~-' . .. '....,: -,''1.< .... .. SP-1I!IØ-1 ILIAMNA DRILLING PROCEDURE REV lOOCT.doc Dt31'¡,...Qn u.¡n ()'¡1 q-nA ~t1IC' Tnro D....fTO t:..1 1 (\/1 0/0'1 I :J 6,000 8,000 --------------- N \ (t) Iliamna 2 Exploration Well Proposed e r COOK INLET PELICAN HILL 1074 II ~ PH. 907-333-8880 i : 2420 FOXHALL DRIVE I: .~ ANCHORAGE, AK 99504-3342 69-6/1252 ii, DATE I ¡; -/ () - 0 3 ¡I: ~ DO R ò~J~~OF_ Stf) ft I";) 1) R.. -" ~f)~c. C. I $ I 0 ~ Î tJ ttJ f!Ç H-V)/P12&"D j, $ DOLLARS tð ~ ¡ (!Yïrsl ~a~i:"i ~~~ I , ~~.. l~~-:~_.~~~;t;,,~~;~rf~~_I~._~~=~~=--==--~~~.==.~~j e Rev: 07/10/02 C\jody\templates . e TRANSMITAL LETTER CHECKLIST CIRCLE APPROPRIATE LETTERIP ARA GRAPH S TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) "CLUE" The permit is for a new wellbore segment of existing weB-, Permit No, API No. Production should continue to be reported as a function· of the original API number stated above. BOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API Dumber (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing . exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST Field & Pool Well Name: ILlAMNA 2 Program EXP PTD#: 2031730 Company PELICAN HILL OIL AND GAS INC. Initial ClasslType EXP I PEND GeoArea 820 Unit On/Off Shore On Administration 1 Pe(l'1)itfee attached_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ . _ _ _ _ _ _ . . Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ . _ _ _ _ _ . _ _ _ . _ _ _ _ _ _ _ _ . . 2 Lease_nIJmber _appropriale_ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ Yes _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ 3 _UniqIJe welLnamea!1d oumb_e( _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ 4 Wen .located in_a_ d_efioed poo1_ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ . _ _ No _ _ _ _ . _ _ _ Explo(aJory well. . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ . _ _ _ _ _ _ . _ _ . _ _ _ _ _ _ _ . . _ _ _ _ 5 WeJlJocated pr.oper _dista!1ce_ f(Om drilling uoitbolJod.a(y_ _ _ _ . _ _ _ _ . _ . _ _ _ _ _ _ _ Yes _ _ . _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 6 WeJlJocated pr.oper _dista!1ce_ f(Om othenvells_ _ _ _ _ _ _ . . . _ _ _ _ _ _ Yes. _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 7Sjjtficient .acreaQ.e.aYail.able in_drilJiOQ.unlt. _ _ _ _ _ _ _ _ _ _ _ _ . _ _ . _ _ _ _ _ _ _ . _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ 8 .If deviated. Is_ weJlbore platiocluded . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ . Vertjcal we.lI_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . _ _ . _ _ _ _ _ _ _ _ _ . _ . _ . _ _ _ _ . _ _ _ _ _ _ _ _ _ 90per.ator onl}' affected party _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ . . _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 100peratorbasappropriateJlondinJorœ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. Yes _ _ _ _ _ _NOTICE.QF_CHANGEO¡::OWNERSHIPa_ndDESlGNAJlQNOfOPERATORto(ms_ filed10J2212003._S¡::Q __ 11 Pe(mitcan be issued wltbout conservation order _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ . Yes _ _ _ _ _ _ form_10~02Breœi'£ed _10/23/03; Letter of.Credjtwith add_endum app(oyed_ by.1_0l2M2003, Std_ _ _ _ _ _ _ _ . _ _ 12 Pe(mitcao be issuedwltboutad_mini~tr.ati'£e_appr.ovaJ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ _ 10/27/2003 13 _C_ao permit.be approved before _15-day_ wajt _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ . 14 We.ll .located within area and_strata .authorized by.lojectioo O(de( # (PIJtlO# in_c.omme!1ts) (For_ NA . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 15 All wells withifU l4_mite_are.a_of (eyiew ideotified (Fo( ~ervlce well ooly). _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 16 Pre.-produ~edi!1jeçtor; duration_ofpre-p(oductiooless_than_3months(For_ser:vicewellonly) _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ 17 ACMP_F.indingofCon.si.sle!1cy_h.asbeenjsslJed_forJhisproiect. _ _ _ _ _. _ _ _ _ _ _ _ _ _.. _ Yes_ _ _ _ _ _ _Deemed_COl1sistenlbo_Office_ofPr.oiectManage_menlandPe(mittiOQ.on1.0l3/2_003._ _ _ _ _ _ _ _ _ _. _ __ 18 _Coodu~lo( ~t(ingprovided _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ . . _ _ Yes _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 19 .Suúace_casiogprotect$.all_known_USDWs _ _ _ _ _ _ _ . _ _ _ . _ _ _ _ _ . _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ . _ _ _ _ _ _ _ 20CMTv.oladequ_ateJo Ci(c_ul.ale_on_conductor_& surf.q¡g _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . Yes _ _ . _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ 21 _CMTv.oladequateJo tie-inJong.slri!1g lo_sIJrJ csg_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ 22 _CMTwill coyer_all koown_pro_ductiye horizon_s_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 23 _Casi!1g de.sig!1S ad_eQua.te. fo( C.T~ B_&_pe(l'1)afr.ost _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 24 AdequaletanJ<age_orre_ser:ve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Pit capacities reviewed i!1 JIi.amna #1.(203-17.2) _ _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 25 Jf.a_re-dr.iII~ has_a_ 1.0,.403 for abandonmenl be~m approved _ _ _ _ _ _. _. _ _ _ _ _ . _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 26 Adequalewellbore.separatlonproposed_ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ Yes _ _ _ _ . _ _ No otherwellb.ore_s_nearb}'. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ . 27 Jf.dlv§u:ter reQ.uired, does ItmeelreguJaJions_ _ _ _ _ _ _ _ _ _ . _ _ _ . . _ _ . _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ Appr Date 28 DrilJiOg fluid_program schematic_&eqjjipJistadequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes. _ _ _ _ Maximum aoticipated Bt-fl=' 9.0_EMW._l='lal1ned MW 10_.Q ppgwitb supplJe_sJo weighJ IJp. TrEM 10/30/2003 29 _BOPEs._d.oJhey meelreguJa.tioo _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . 30 BOPEpre.ss ratiog app(opr.iate;_testlo_(put psig in_comments) _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ Yes _ _ _ _ Calculated_MASP_2024 p~i. Plaon_ed BOP Jest pre~s_u(e_3_000 psj. _ _ _ _ _ _ _ _ _ _ _ _ _ _ 31Choke_manjfold compJies_ w/APLRF'-53 (May 84)_ _ _ _ _ . _ _ . _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 32 Work will occur. withoutoperation .sbutdown _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ . 33 .Is prese!1ce of H2S gas_ prob.able _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ . _ _ _ _ . _ _ No _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ 34 Mecha_nicaLc.oodjtiO!1.ot wens within AOR yerified (For service well onJy) _ _ _ . _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 35 Pe(mitcaobeissuedw/ohydr.ogen_s_ulfidemeasjjœs_ _ _ _ _ _ _ _. _. _ _ _ _ _ _ _ Yes_. _ _ _ _ _None_enco_u!1teœdln_offsetwells,.Rig~ensor~willbeutllized, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _. 36 .Data_preseotedon_pote.ntialoverpres_sure_zones_ _ _ _ _ _ _ _. _ _ _ _. _ _ _ _ _ _. _. Yes_ _ _ _ _. _Non_e_expe_cled._Op_eratorlsaw.aœ_o.fmlJdpr.ofilesusedto_drilJoffselweJls.Wellsitegeologislwillbe_ __ Appr Date 37Seismicanalysjs_ofsbaJlowgas_z.ooes_ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ Yes_ _ _ _ _ _on_site.when_drilling_b_elow.550'MD_._EJectr0l1icdrillinginformatioos}'stemwillbe.used. _ _ _ _ _ _ _ _ _ _ _ __ SFD 10/23/2003 38 .Seabed _condltioo survey (if off-~h.or.e>- _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ . _ _ _ _ _ . _ . . _ _ _ _NA . _ _ _ No evjd_e!1ce_of shaJlow gas_h.azards_on.sparse sejsmic. _Rig will hav.e.9a~ detectors. _ _ _ _ . _ _ _ _ _ _ _ _ _ . 39 Conta_cl namelphoneJor.w:eekly progress_reports [explorato(y o!1IYl . . _ _ _ _ _ _ _ _ _ _ _ . . . Yes _ _ _ _ _ _ _ Arlen _Ehm. 333:8.880 _ _ _ _ . . _ _ _ _ _ . . _ _ _ _ . _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ Engineering Public Commissioner: Date Commissioner ~~~ Appr Date . Engineering Geology Geologic Commissioner: PT) Well bore seg Annular Disposal D D - - - - - - - - - - - - - - - - - - - - -- - - - - - - . 'I!ó¡..~ .- Date: An inclination only survey is required on this vertical well. Mudlog will consist of output data from electronic drilling data system. Cuttings samples waived due to close proximity (within 1-1/2 miles) to two existing exploratory wells having complete samples from 30' to >6700' MDITVD. Openhole logs waived: will be drilled with casing; pulsed neutron I GR will be run in casing. Date /0/36/3 ~ ~~