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204-187
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. ~ º y.. - J <6- 7 Well History File Identifier Organizing (done) D Two-sided 1111'111111 ""1111 RESCAN ~olor Items: D Greyscale Items: DIGITAL DATA D Diskettes, No. D Other, Norrype: D Poor Quality Originals: D Other: NOTES: BY: ~ Date1/"?IJ/oh Project Proofing BY: ~ Maria) Date c¡ ¡';m 10 Þ c1 X 30:= (PO + Date C¡/36Joh Scanning Preparation BY: ~ Production Scanning D Rescan Needed 11/111/11/1/1111111 OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) D Logs of various kinds: D Other:: rnP 151 III 111/1111I11 /11/1 -JI11P (oð ~p 151 o := TOTAL PAGES (Count does not include cover sheet) 151 1111111111111'"11I Stage 1 Page Count from Scanned File: (p l.} (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: BY:~. Date: q/3D/Oh Stage 1 If NO in stage 1, page(s) discrepancies were found: BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: vÝES NO 151 r11 f YES NO 151 III II 1/1111I11111/1 /1111111111111 "III 151 Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc • • §y ~. w '" < ° ^ ~~.,~ MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:~LaserFichelCvrPgs_Inserts~Microfilm_Marker.doc RE: Beaver Creek # 15 . . No drilling operations have started on this well. It is on hold for now. Thanks, Kaynell From: Howard Okland (mailto:howard_okland@admin.state.ak.us] Sent: Thursday, September 28, 2006 12:35 PM To: Zeman, Kaynell J. Subject: Re: Beaver Creek #15 Kaynell, The reason that I have asked about BCU 15 is that the permit expired as of the 27th of September, 2006. A new permit will be required if drilling operations had not started by the 27th. Have drilling operations started? Howard Zeman, Kaynell J. wrote: No. We drilled 14 then 16. Have not yet drilled 15. From: Howard Okland fmailto:howard ok!and@admin.state.ak.us] Sent: Thursday, September 28, 2006 12:10 PM To: Zeman, Kaynell J. Subject: Beaver Creek #15 Kaynell, I need some help. Could you please tell me if Beaver Creek #15 has been drilled? TNX Howard 1 of! 9/28/2006 11 :00 AM ~C? @' . lID . ....¡ FRANK H. MURKOWSKI, GOVERNOR AI4ASIiA. OIL AlQ) GAS CONSERVATION COMMISSION 333 w. -¡m AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Willard J. Tank Advanced Senior Drilling Engineer Marathon Oil Company P.O. Box 3128 Houston, TX 77253 Re: Beaver Creek # 15 Marathon Oil Company Permit No: 204-187 Surface Location: 91' FSL, 1443' FEL, SEC 33, T7N, RI0W, SM Bottomhole Location: 219' FSL, 252' FEL, SEC. 33, T7N, RlOW, SM Dear Mr. Tank: Enclosed is the approved application for permit to drill the above referenced development well. 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. Marathon Oil Company assumes the liability of any protest to the spacing exception that may occur . 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. 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 (907 659- 7 (pager). BY ORDER º~THE COMMISSION DATED thisH day of September, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. . . Worldwide Drilling North America Marathon Oil Company P.O. Box 3128 Houston, TX 77253-3128 Telephone 713-629-6600 Fax 713-499-6737 September 22, 2004 John Norman Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Ave, Suite 100 Anchorage, AK 99501 Reference: Drilling Permit Application Field: Beaver Creek Field Well: Beaver Creek Unit BC-15 RECEIVED SEP 2 2 2004 Alaska Oil & Gas Cons. Commissíon Anchorage Dear Mr. Norman Enclosed please find the PERMIT TO DRILL application, along with the associated attachments and filing fee of $100. The intent is to drill a Beluga well in the Beaver Creek Unit. No completion is desired in either the Sterling or Tyonek pools. Please note that Marathon is requesting a waiver for 20 ACC 25.035 (e) (1) (b) requiring a two pipe ram stack. The request is specified on page 13 of the attached drilling prognosis. If you require further information, I can be reached at 713-296-3273 or bye-mail at wjtank@ marathonoil.com. Sincerely, . J j ~' Ai' . ·1' / L I f i . " . ,; i I - F\ . r. ,i '/{I¿ jI II F1 ;' v,. . \.-..,i.f.. ' . 1,,/\/ i / ß¡;" . ./\,.JJ; v./ ï .... _,' ,_^ ______ Willard J. Tank Advanced Senior Drilling Engineer Enclosures n.1R\G\NAL .;. iNGÄ- '/~¡U'0t a STATE OF ALASKA a RECJ=IVED "-'KA OIL AND GAS CONSERVATION C<WI1ISSION PERMIT TO DRILL SFP 2 2 2004 20 AAC 25.005 AI . f'nmmit&ion 1b. Current Well Class: Exploratory 0 mvelopmerrt'bfl ¡,;ur:¡ "NIWfipreZone 0 Stratigraphic Test 0 Service 0 DevelopmJko§lwr~ "Single Zone [2] 5. Bond: Blanket [2] Single Well 0 11. Well Name and Number: Bond No. 5194234 BC #15 / 6. Proposed Depth: 12. Field/Pool(s): MD: 8,808 TVD: 8,687 Beaver Creek I Beluga 7. Property Designation: A-028083 1a. Type of Work: Drill 0 Redrill 0 Re-entry 0 2. Operator Name: Marathon Oil Company 3. Address: P.O. Box 3128, Houston, TX 77253 4a. Location of Well (Governmental Section): Surface: 91' FSL, 1,443' FEL, Sec. 33, T7N, R10W, S.M. Top of Productive Horizon: 216' FSL, 452' FEL, Sec. 33, T7N, R10W, S.M. Total Depth: 219' FSL, 252' FEL, Sec. 33, T7N, R10W, S.M. 4b. Location of Well (State Base Plane Coordinates): Surface: x - 314,312.737 Y - 2,430,050.486 Zone - 4 16. Deviated wells: Kickoff depth: 2,300 feet Maximum Hole Angle: 12.88 degrees 8. Land Use Permit: 13. APproxi~. ud Date: OctOb'l~4 9. Acres in Property: 14. Distance to Nearest 2,560 Property: 390 ft (A-028118) 10. KB Elevation 15. Distance to Nearest Well (Height above GL): (21' AGL) 162 feet Within Pool: 1,850 ft. to BC #14 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3,840 Surface: 1,945'/ Setting Depth Quantity of Cement c.f. or sacks 18. Casing Program: Specifications Size Hole Casing Weight Grade Coupling Length Driven 20" 133 K-55 PE 123' 16" 133/8" 68 L-80 BTC 2,079' 12 1/4" 95/8" 40 L-80 BTC 7,125' 81/2" 3 1/2" 9.3 L-80 EUE 8,787' Top Bottom MD TVD MD TVD 0' 0' 144' 144' 0' 0' 2,100' 2,100' 0' 0' 7,146' 7,037' 0' 0' 8,808' / 8,687' 567 sacks 1 ,224 sacks 805 sacks (including stage data) 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Structural Conductor Surface Intermediate Production Liner Length Perforation Depth MD (ft): Size Cement Volume MD TVD Perforation Depth TVD (ft): Time v. Depth Plot U Shallow Hazard Analysis U Drilling Fluid Program [2] 20 AAC 25.050 requirements 0 Date Contact Filing Fee l0 BOP Sketch l0 Property Plat [2] Diverter Sketch [2] 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. 20. Attachments: Printed Name Willard J. Tank Signature A 1/ ¡jíJ _ I ~\ /1 ¡ _ J/f¿l.Á()./1.Q1.¥· h~ ß··'..,_,.._r·~ .:/' Permit to Drill Number: 2ð 7"-/'6" 7 Conditions of approval : API Number: 50- /33-' S pies required Yes yd ogen S~fide measures Yes o t= 25'00 llJi ,. ;.¡ , / Form 10-401 Revised 06/2004 Drilling Program l0 Seabed Report 0 Title Advanced Senior Drilling Engineer Phone 713-296-3273 Commission Use Only permit Approval 2.0 S 7' S Date: ç-þ?/I?'-I o No 1š. Mud log required o No J2J Directional survey required Date September 22, 2004 Isee cover letter for other requirements. Yes 0 Yes~ No ~ No 0 APPROVED BY 1z-r/()f '-"" o R I G1NÄJrON Date: Submit in Duplicate . . MARATHON MARATHON Oil COMPANY DRilliNG PROGRAM Beaver Creek Unit BC #15 Original 9/22/04 Originator: Drilling Superintendent: North America Drilling Manager: W.J. Tank }J/ r\J1 , ,f':/" P. K. BerQa B.J. Rov Page 1 of 14 . . Table of Contents General Well Data................................................................................................................................................................... 3 Geologic Program Summary ................................................ ..... ............................................................................ ............. ..... 3 Summary of Potential Drilling Hazards....................................... .................................................................... ......................... 4 Formation Evaluation Summary................................... ................ .............. ................................... ............... ........................... 5 Drilling Program Summary ........................................................................................................................... ..... .......... ............ 5 Casing Program................................................. ......... ...................................................................................... ........ ..... ..........6 Casing Design........................................................................................ ............................................................... ........ ....... ... 6 Maximum Anticipated Surface Pressure.............................................................................................. ................................... 7 BOPE Program ........................................................................................................................................................................8 Wellhead Equipment Summary............................................................................................................................ ...... ............ 9 Directional Program Summary ............................................ ......... ............................................................................... ............ 9 Directional Surveying Summary .................................................................................................................................. .......... 1 0 Drilling Fluid Program Summary........................................................................................................................................... 1 0 Drilling Fluid Specifications.................................................................................................................................................... 11 Solids Control Equipment.......................................................................................................................................... ............ 11 Cement Program Summary.......................................................................................................................................... ......... 12 Regulatory Waivers and Special Procedures.......................................................................................... ............. ........ ......... 12 Bit Summary............................................................................................................................................................... ...........13 Hydraulics Summary............................................................................................................................................................. 13 Formation Integrity Test Procedure...................................................................................................................................... .14 Page 2 of 14 General Well Data Well Name SUrface Loœtion SIotIPad KeElev. Ground Level EIev. Perm. Datum Water DtpIh Water ProtectIOn DfpIh Comments: . Be #15 91' FSL, 1,443' FEL, Sec. 33, T7N, R10W, S.M. ,. BCU Pad 1 A Fie(d Beaver Creek 162 CountyIProvlnce Kenai peninsula 141 State I Country Alaska KB Total MD 8,808' NlA Total TVO 8,687' , ~ was .CQde Spud Date APt No. Well CIu8 RIg Cønttactor RIg Name DX.04.10944.CAP.DRL 10/3104 (est.) Development Glacier Drilling #1 Geoloaic Proaram SUmmary MD . RKB TVD - AKB Pore Pressure Pore Pl1i8$UCe PoIdIIe Auld Formation (It) (ft) (pei) (ppg) I...IthøIOI:W 00cItant Sterling B·3 (Not a Prod Target) 5,184 5,122 4.40 Sandstone Gas I Water 9.éJ Sterling B-3A (Not a Prod Target) 5,256 5,192 4.40 Sandstone Gas I Water Sterling B-4 (Not a Prod Target) 5,343 5,277 8.00 Sandstone Gas I Water Top U. Beluga (Not a Prod Target) 5,953 5,872 8.50 Sandstone Gas Top M. Beluga (Not a Prod Target) 6,533 6,437 8.50 Sandstone Gas Base M. Beluga Cong!o 7,146 7,037 8.50 Sandstone Gas L.Beluga LB-15 (Primary Target) 7,171 7,062 5.80 - 9.40 Sandstone Gas L.Beluga LB-16 (Primary Target) 7,246 7,137 5.80 - 9.40 Sandstone Gas L.Beluga LB-17 (Primary Target) 7,347 7,237 5.80 - 9.40 Sandstone Gas L.Beluga LB-18 (Primary Target) 7,423 7,312 5.80 - 9.40 Sandstone Gas L.Beluga LB-19 (Primary Target) 7,488 7,377 5.80 - 9.40 Sandstone Gas L.Beluga LB-20 (Primary Target) 7,554 7,442 5.80 . 9.40 Sandstone Gas L.Beluga LB-21 (Primary Target) 7,665 7,552 5.80 . 9.40 Sandstone Gas L.Beluga LB-22 (Primary Target) 7,740 7,627 5.80 - 9.40 Sandstone Gas L.Beluga LB-23 (Primary Target) 7,801 7,687 5.80 - 9.40 Sandstone Gas L.Beluga LB-24 (Primary Target) 7,886 7,772 5.80 - 9.40 Sandstone Gas L.Beluga LB-25 (Primary Target) 7,967 7,852 5.80 - 9.40 Sandstone Gas L.Beluga LB-26 (Primary Target) 8,052 7,937 5.80 - 9.40 Sandstone Gas L.Beluga LB·27 (Primary Target) 8,153 8,037 5.80 - 9.40 Sandstone Gas L.Beluga LB·28 (Primary Target) 8,214 8,097 5.80 - 9.40 Sandstone Gas L.Beluga LB-29 (Primary Target) 8,350 8,232 5.80 - 9.40 Sandstone Gas L.Beluga LB-30 (Primary Target) 8,430 8,312 5.80 - 9.40 Sandstone Gas L.Beluga LB-31 (Primary Target) 8,531 8,412 5.80 - 9.40 Sandstone Gas L.Beluga LB-32 (Primary Target) 8,591 8,472 5.80 - 9.40 Sandstone Gas L.Beluga LB-33 (Primary Target) 8,637 8,517 5.80 - 9.40 Sandstone Gas Top U. Tyonek (Not a Prod Target) 8,808 8,687 8.50 Coal, Silt, Shale Gas Comments: Page 3 of 14 · , From Lea8eIBIock LJne8 I..atitude I.ongitud4Iî UTM NoI1h (Y) UTM Eaet (x) ToItnnoe Surface LocatiOn Coordinates 91' FSL, 1,443' FEL, Sec. 33, T7N, R10W, S.M. 600 38' 50.945" N 151002' 04.806" W 2,430,050.486' 314,312.737' ,. Directional Target L.Beluga LB-15 Top U. Tyonek (TD) hID (It) 7,171 8,808 TVD (ft) 7,062 8,687 Location 216'FSL, 452'FEL,Sec. 33, T7N, R10VV, S.M. 219'FSL,252'FEL, Sec. 33, T7N, R10VV, S.M. HoriZOntal DispIaoement(ft) +Nf-S +SI·W (Y) (X) 125 991 128 1,191 ToIef8nce (It) Depth Circle 100' radius Circle 100' radius Comments: Summary of Potential Drillina Hazards Hazard Event Lost Circulation in Low Pressure Sterling and Beluga sands Discu$8iOn Control losses by using sufficiently sized LCM. Comments: Potential Hazards Statement To comply with state regulations the Potential Hazards section and the well shut-in procedures must be posted in the drillers dog house. The man on the brake (driller or relief driller) is responsible for shutting the well in (BOPE or diverter as applicable) as soon as warning signs of a kick are detected and an influx is suspected or confirmed. A copy of the approved permit to drill must be kept on location and be readily available to the AOGCC or BLM inspector. This well's primary objective is gas and no oil sands are expected to be encountered. No H2S is anticipated. / Gas sands will be encountered from +/- 5,184' MD (5,122' TVD) to total depth of the well. These sands will run from highly depleted to slightly above normal pressure. Lost circulation and differential sticking are potential hazards in some of the Sterling and Beluga sands. The Flo-Pro mud system that will be used to drill the well will help reduce these risks and lost circulation materials will be on location. Weighting material will available on location for proper well control. Page 4 of 14 · , Formation Evaluation Summary IntttMIl LWD Surface None 0' - 2,100' MD Intermediate None 2,100' -7,146' MD Production None 7,146' - 8,808' MD Completion NIA Electric Logs Mud Logs None None None Basic with GCA, shale density, temperature in and out, sample collection (10' samples). Basic with GCA, shale density, temperature in and out, sample collection (10' samples). NIA Reeves Quad Combo & MDT. Pull GR- Neutron to surface inside casing. GR, CCL Coring Requirements: None Comments: Drillina Proaram Summary CONDUCTOR: 1. Drive 20" conductor to +/-100 ft. RKB. 2. Move in and rig up rotary drilling rig. 3. Install starting head 20" SLC x 21 1/4", 2M flanged. 4. Nipple up 21 1/4", 2M diverter, 16" diverter valve, and 16" diverter line. / 5. Function test diverter and diverter valve. SURFACE: 1. Drill a 16" hole to 2,100' MD (2,100' TVD) per the directional plan. 2. RIH with 13 3/8" casing and hang off in the elevators. Make up stab-in sub and centralizer on 5" drill pipe. TIH with inner / string and latch into stab-in float collar. Cement 13 3/8" casing. Sting out, shear out drill pipe wiper plug, and circulate drill pipe clean. TOOH with inner string. 3. Cut off 13 3/8" casing. ND diverter. 4. Install 133/8" slip lock connection X 135/8" 5M flanged multibowl wellhead. 5. NU 135/8" 5M BOP'S. Test BOP'S and choke manifold to 250/2,500 psi. / 6. Set wear bushing. 7. Test surface casing to 2,500 psi. INTERMEDIATE: 5. 6. 7. Drill out float equipment and make 20' of new hole. CBU. Test shoe to leak off. Estimated EMW is 14.3 ppg. Drill 12 1/4" directional hole to approximately 6,533 ft MD (6,437 ft TVD) as per directional plan, short tripping as necessary (1,000' or 24 hours, but can be extended depending on hole conditions). This represents the approximate top of the conglomerate. Trip out of hole with the PDC bit. TIH with an insert bit and continue drilling to the target depth of 7,146 ft MD (7,037 ft TVD) as per directional plan. At TO circulate hole clean. Make wiper trip. TOOH. Change out variable pipe rams with 9 5/8" casing rams. Run test plug and test casing rams to 2,500 psi. Run and cement 9 5/8" casing. Land hanger in multibowl wellhead. Back out landing joint. Change out 9 5/8" casing rams with variable pipe rams. Run test plug and test pipe rams to 250/2,500 ~. / Set wear bushing. Test casing to 2,500 psi. / 1. 2. 3. 4. 8. Page 5 of 14 · , PRODUCTION: 7. Orill float equipment and 20' of new formation w/8 1/2" bit. CBU./ Test shoe to leak off. Estimated EMW 15.0 ppg. Drill a 8 1/2" hole to 8,808' MO (8,687' TVD) per the directional program, short tripping as necessary (1,000' or 24 hours, but / can be extended depending on hole conditions). At TO circulate hole clean. Make wiper trip. TOOH. RU logging company. Run open hole logs as per plan. RO logging company. TIH w/8 1/2" bit to TO for wiper trip. TOOH to 9 5/8" shoe and circulate until log evaluation is complete for picking EXCAPE / modules. After picks are made, trip to TD and circulate clean. TOOH and laydown BHA and drill pipe. Pull wear bushing. RU and run 31/2" EXCAPE casing string. RU logging company to correlate EXCAPE modules to open hole logs. RO logging company. Cement 3 1/2" casing while reciprocating. Bump plug with 500 psi over displacement pressure. WOC. PU 3 1/2" casing. PU BOP stack. Run control and electric lines out tubing head outlet. Set slips. Cut 3 1/2" casing. LD BOP. Set 31/2" packoff. NU 135/8" 5M X 31/8" 5M tubing head adapter and 31/8" 5M tree. Test tree to 5,000 psi. / Rig down and move out drilling rig. / 1. 2. 3. 4. 5. 6. 8. 9. 10. 11. Note: Drill all hole sections with 5" drillpipe. Perforating guns will be run on the outside of the 3 1/2" production casing with a flapper valve just below each perforating gun. Guns to be activated by control line to surface. COMPLETION: Completion will be done without a rig. CasinQ PrOQram Casing Size (In) 13 3/8 95/8 31/2 Top Surface Surface Surface Bottom 2,100 7,146 8,808 Weight (1bsIIt) 68 40 9.3 Grade L-BO L-80 L-80 Connection API R¡dIngs Makeup Ii !~ Ii O.D. Torque Hole SIze Type (in) (ft-lbs) (in) ¡.;.~ BTC 14.375 N/A* 16 5,020 2,260 1,545 BTC 10.625 N/A* 121/4 5,750 3,090 979 8rd 4.5 3,200 81/2 10,160 10,530 207 MQ(ft) Comments: * The make up of the buttress connection will be to the proper mark. CasinQ Desiqn Casing Shoe Safety FactoI8 C~ SettIng Mud Wt Frac. Form Maximum Surface I j SIze Weight Depth When Set Gtad Prees Pressure I (in) (1bIft) Grade (TVD) (lbIgaI) (lbIgaI) (lblgaJ) (psi) 13 3/8 68 L-80 2,100 9.0 / 14.3 8.5 1,406 3.14 1.74 5.96 ~_. 95/8 40 L-80 7,037 9.5 15.0 8.5 1,945 1.20 ~ 2.69 ,.- 31/2 9.3 L-BO 8,687 9.5 16.0 8.5 1,945 1.14 2.11 1.61 Comments: Page 6 of 14 · , Maximum Anticipated Surface Pressure SettIng Depth CasIng SIze TVO MAWP · (in) (ff) (psi) 13318 2,100 3,438 9 5/8 7,037 3,842 31/2 8,687 6,886 * MAWP = Maximum allowable working pressure .. MASP = Maximum anticipated surface pressure MASP" MudIGu (psi) Ratio 1,406 30170 1,945 30170 1,945 30170 Comments: MASP I MAWP CALCULATIONS: Surface casing: 13 3/8" (2,100' MD, 2,100' TVD) MASP'rac = ((Fracture gradient at shoe + S.F.) x .052 x TVDshoe) - Hydrostatic pressure of gas column at the shoe. MASP,rac = (14.3 ppg + 0.5 ppg) x .052 x 2,100' . (.1 psilft x 2,100') MASP,rac = 1,616 psi· 210 psi MASP,rac = 1,406 psi. MASPbhp = BHP open hole td - Hydrostatic pressure of mud portion - Hydrostatic pressure of gas portion MASPbhp = (8.5 ppg x .052 x 7,037') - (0.3 x 9.5 ppg x .052 x 7,037') - (0.7 x 0.1 psilft x 7,037') MASPbhp = 3,110 psi - 1,043 psi - 493 psi MASPbhp = 1,574 psi MASP = MASP"" =~Sl MAWP = (0.7 x Casing Burst) - (Mud Wt. - Backup Fluid Wt.) x .052 x TVD MAWP = (0.7 x 5,020) - (9.0 - 8.3) x .052 x 2,100' MAWP = 3,514 psi -76 psi = 3,438 psi Intermediate casing: 95/8" (7,146' MD, 7,037' TV D) MASP,rac = «(Fracture gradient at shoe + S.F.) x .052 x TVDshoe) - Hydrostatic pressure of gas column at the shoe. MASP,rac = (15.0 ppg + 0.5 ppg) x .052 x 7,037' - (.1 psilft x 7,037') MASP,rac = 5,672 psi - 704 psi MASP,rac = 4,968 psi. MASPbhp = BHPopen hole td - Hydrostatic pressure of mud portion - Hydrostatic pressure of gas portion MASPbhp = (8.5 ppg x .052 x 8,687') - (0.3 x 9.5 ppg x .052 x 8,687') - (0.7 x 0.1 psilft x 8,687') MASPbhp = 3,840 psi - 1,287 psi - 608 psi MASPbhP = 1,945 psi í\ MASP = MASP"", =t~,J.i MAWP = (0.7 x Casing Burst) - (Mud Wt. - Backup Fluid Wt.) x .052 x TVD MAWP = (0.7 x 5,750) - (9.5 - 9.0) x .052 x 7,037' MAWP = 4,025 psi - 183 psi = 3,842 psi Page 7 of 14 · Production casing: 3 1/2" (8,808' MD. 8.687' TVD) , MASP,rac = ((Fracture gradient at shoe + S.F.) x .052 x TVDshoe) - Hydrostatic pressure of gas column at the shoe. MASP,rac = (16.0 ppg + 0.5 ppg) x .052 x 8,687' - (.1 psilft x 8,687') MASP'rac = 7,453 psi - 869 psi MASP,rac = 6,584 psi. MASPbhp = BHP open hole td - Hydrostatic pressure of mud portion - Hydrostatic pressure of gas portion MASPbhP = (8.5 ppg x .052 x 8,687') - (0.3 x 9.5 ppg x .052 x 8,687') - (0.7 x 0.1 psilft x 8,687') MASPbhp = 3,840 psi - 1,287 psi - 608 psi MASPbhp = 1,945 psi MASP = MASP"" =64' MAWP = (0.7 x Casing Burst) - (Mud Wt. - Backup Fluid Wt.) x .052 x TVD MAWP = (0.7 x 10,160) - (9.5 - 9.0) x .052 x 8,687' MAWP = 7,112 psi - 226 psi = 6,886 psi BOPE Proaram CasIng CasIng Size (in) Casing Test Test Fluid PrØ$S Density (psi) (lblgaI) MAWP (PSI) MASP (psi) Surface 13 3/8 3,438 1,406 2,500 9.0 Intermediate 95/8 3,842 1,945 2,500 9.5 Production 31/2 6,886 1,945 2,500 9.5 Comments: Blowout Preventers BOPS Size & Rating (1) 13-5/8" 5M annular (1) 13-5/8" 5M pipe ram (1) 135/8" 5M blind ram (1) 13-5/8" 5M drilling spool with 3-1/8" 5M outlets (1) 13-5/8" 5M annular (1) 13-5/8" 5M pipe ram (1) 135/8" 5M blind ram (1) 13-5/8" 5M drilling spool with 3-1/8" 5M outlets (1) 13-5/8" 5M annular (1) 13-5/8" 5M pipe ram (1) 13 5/8" 5M blind ram (1) 13-5/8" 5M drilling spool with 3-118" 5M outlets Tøt Preesure I.owIHIgh (psi) 250/2,500 - 250/2,500 -- 250/2,500 /' The blowout preventer stack will consist of a 13-5/8" x 5000 psi annular preventer, a 13-5/8" x 5000 psi double gate ram type preventer with blind rams in the bottom and pipe rams in the top and a 13-5/8" x 5000 psi drilling spool (mud cross) with 3-118" x 5000 psi outlets. / The choke manifold will be rated 3-1/8" x 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a poor-boy gas buster, and a vacuum-type degasser. A flow sensor will be installed in the flowline and the mud pits will Page 8 of 14 · , contain sensors to measure the volume of fluid in the surface mud system. Both sensors will contain readouts convenient to the drillers console. Casing Test Pressures Casing test pressures are based on the lesser of (1) MASP, or (2) 70% of rated burst pressure of the casing adjusted for the mud weight used during the test less a 8.3 ppg back-up unless otherwise noted. Wellhead EauiDment Summary Comporaent Casing Hanger Type 13 5IS" x 9 5IS" Fluted Mandrel 13 5IS" x 3112" Manual Slip Description 13-5IS" 3M X 13-3/S" Slip Lac WI 2, 2" LPO, Landing Base for 20" Conductor, U, AA, PSL 1, PR1 13-5/S" 3M Studded Bottom X 13·5IS" 5M Fig Top, WI 2, 2-1/16" 5M Studded Outlets, U,AA,PSL 1,PR1 Adapter Flange 13-5/S" 5M X 3-1/S" 5M WI Seal Pocket and 3" H BPV Threads Comments: Control lines and electric cable for the EXCAPE system will be routed through the tubing head side outlet. Casing Head Tubing Head Directional Proaram Summary Build Turn CoordinaRIcJ Sec. MD TVD Rate Rate Dogleg inclination AzImuth +NI-8 +ÐW VI No. 0e8cripti0n (ft) (ft) (o/1()O') (°'100') (0/100') (deg) (deW (It) (fQ (Ie) 1 Tie On 0 0 0 0 0 0 0 0 0 0 2 KOP 2,300.00 2,300.00 0 0 0 0 0 0 0 0 3 Build up Section 2.00 12.85 /2.00 S2.72 4 End of Build 2,943.86 2,93S.45 2.00 12.85 2.00 12.S8 S2.72 9.14 71.47 72.03 5 Hold Section 0 0 0 12.88 82.72 6 End of Hold 6,873.12 6,76S.89 0 0 0 12.88 82.72 120.13 940.09 947.54 7 Drop Section -1.97 2.14 2.00 S9.10 8 End of Drop to the 7,170.83 7,062.00 -1.97 2.14 2.00 7.02 89.10 124.63 991.23 99S.86 Target 9 TD 8,808.09 8,687.00 0 0 0 7.02 89.10 127.78 1,191.21 1,198.05 Comments: Vertical section calculated from a reference azimuth of 83.88° taken from surface location to bottom hole location. Potential Well Interference: Well BC #14 BC #1A Distance (ft) 53.42 120.91 Depth (MD) 1,612 Surface No serious interference exists. See attached directional plan and anticollision analysis for more details. Page 9 of 14 · I ê ~ ê ~ ~ ~ -= ~ 0. j:. ð .r:: 1:: B ~ 'e ~ ~ ~ 0 (J) f- Vertical Section at 83.880 [250Oft/in) Directional Surveyina Summary Interval 0-2,100' 2,100' - 7,146' 7,146' - 8,808' Magnetic MuItishot MWD Survey X X X Comments: Drillina Fluid Proaram Summary IntervaI- TVD Fmm To (It) (It) Density (lbIgaI) Auid Deecription o 2,100 Gel I Gefex Spud Mud 8.6 - 9.4 2,100 7,037 9.0 - 9.5 6% Flo-Pro wI Safecarb 7,037 8,687 9.0-C..5) l~/' 6% Flo-Pro wI Safecarb Comments: , West(-)IEast(+) [50Oft/in Gyro MuftIshot Cornmenta AddItives Gel, Gelex, Soda Ash, Caustic, Barite, POlypac Supreme UL, Sodium Meta Bisulfate Flo-Vis, PoluPac UL, KCI, SafeCarb F&M, KlaGard, Barite, Caustic, Conqor 404, Sodium Meta Bisulfate Flo-Vis, PoluPac UL, KCI, SafeCarb F&M, Barite, Caustic, Conqor 404, Sodium Meta Bisulfate UioimUJn InV«ÜOlY Gel ViIco8ifier Baritt See mud prognosis for details. The mud system from the intermediate section will be utilized in the production hole section instead of building a new mud for that section. Sized CaC03 (SafeCarb) will be used to controlleakoft. Page 10 of 14 · , Drillina Fluid SDecifications Interval- TVD From To (ft) (ft) o 2,100 2,100 7,037 7,037 8,687 Density (lbIgaI) 8.6 - 9.4 9.0 - 9.5 9.0 - 9.5 LSRV Vis 1 min PV (seclqt) (lbJ1 DOff) (oP) 60 - 100 N/A 30,000 8 - 12 30,000 10 - 14 yp Fluid Loss Drill Solids (1bI100 tt2) (00) pH (%) 25-35 NC - 12 +/- 9.5 <7.5 7-9 +1- 9.5 +1- 5 6-8 +/- 9.5 +/- 5 Comments: As a standard practice for long string completions, the drilling mud that will remain above the top of cement on the 3 %" production casing will be treated with corrosion inhibitor (Conqor 303A) at a concentration of 1 drum per 100 barrels of drilling fluid. See mud prognosis for details. Solids Control EauiDment Interval o - 8,808' MD I i I I l ! t I ~ s I ð ~ x x x x Cornmenta Closed Loop System, Full Containment Item Shaker 2 - Derrick Model 2E48-90F-3T A Deeander' NJA DeaiIter 1 - Derrick Model 0522 Mud CIeaoer N/A Centrifuge 2 - MUSwaco units Cuttings Dryer NJ A Cuttlngslnjectlon Marathon G&I Facility Zero DiIIIcharge NJ A Equipment SpeoItIœtions (quantity. design type, brand. model. fk>w capacity, étO) Comments: The solids control equipment will consist of two flowline cleaners, a desilter, and the MI centrifuge van. Included will be equipment to de-water the underflow from the mud processing equipment to allow for disposal of the cuttings and solids by slurrification and injection into the disposal well at the KGF. Page 11 of 14 · , Cement Proaram Summary Depth Gauge Top of Cement Open Casing Hole Ann Vol Slurry woe Hole SIze Me TVD Size Me TVD To TOO Vol TIme e- (In) (ft) (ft) (In) (ft) (It) (tf') (ffI) (In) C"o} 13 3/8 2,100 2,100 16 0 0 935 1,423 8 50 95/8 7,146 7,037 121/4 2,000 2,000 1,614 2,201 8 35 31/2 8,808 8,687 81/2 6,600 6,503 740 934 N/A 35 MIx Water' ~ Casing /' Sluny TOO 8nngth Size Density Qty Yield Vol MD Qty WL FW (peØ (In) Slurry Cement DesoriptIon (H:llgeI) (ax) (tt'Isx) (ft') (It) (gaJlax) Type (co) <"'J 8br 24br 13 3/8 Tail Type I Cement 12.0 567 2.51 1,423 0 11.28 Fresh 526 0 196 818 Leed Class "G" 12.5 830 2.10 1,744 2,000 11.97 Fresh 273 769 95/8 Tail Class "G" 15.8 394 1.16 457 6,146 4.97 Fresh 0 0 1,043 3,163 31/2 Tail Class "G" 15.8 805 1.16 934 6,600 4.92 Fresh 24 0 226 2,632 Comments: See cement prognosis for details and spacer specifications. Reaulatorv Waivers and Special Procedures I AOGCC Regulation 20 ACC 25.035 (e) (1) (b) I Requirement for 2 pipe rams, one blind ram, and one annular for a API 5K or above BOP stack. Marathon is requesting a waiver from the above regulation for BC #15. We are requesting that the BOP stack be configured with one pipe ram instead of two, due to rig height restrictions in the running of the 31/2" production casing. The height restriction involves having rig crew members routing control line and electrical line through one of the tubing head outlets after the 31/2" casing is cemented and the BOP stack is picked up. This is prior to setting the casing on slips and cutting the casing sticking up. These lines control firing of the perforating guns and the monitoring of downhole pressure and temperature in our EXCAPE completion system. Similar waivers have been requested for EXCAPE completion wells in the Beaver Field and were granted. No problems were encountered while doing this operation on any of the wells. Also due to MASP below 2,000 psi, only a 3,000 psi * BOP stack would be required for this work if it was economic to change out BOP stacks for this well. If a 3,000 psi BOP .' stack was used then no waiver would be necessary. Utilizing the 13 5/8" 5M stack currently found on the Glacier Drilling #1 rig is more than sufficient for pressures to be encountered. ND wcJ\lW ~S5.(Afl ' ---- Page 12 of 14 · , Bit Summary 1nWrvaJ.. Me Type From To Size (It) (ft) (in) ~ Model No. IADC 0 2,100 16 Christensen MX-1 115 2,100 6,533 121/4 Christensen MX-C1 117 6,533 7,146 121/4 Christensen MX-C09D 437 7,146 8,808 81/2 Christensen HCM605 M323 Comments: Recc:mmended WOB (kIpe) 1 - 4 RPM 80 - 350 80 - 300 Ealll.Mør.t .... AOP .... ... 2-5 24 - 61 Motor Up to 25 Motor In the 121A" hole the mill tooth bit will be utilized until dull, somewhere around the top of the conglomerate (approx. 6,533' MD). The MX-C09D will be utilized to drill the conglomerate. Back up bits for the 8 W' hole section will consist of mill tooth and TCI tricone bits. See bit prognosis for additional information. Hvdraulics Summary Rig mud pumps available are shown below. Max Press 0 OispIacemeot 0 UnerID Stroke 90% WP 95% eft Max Rate Hokt Sections IJød Qty Make Model (in) (in) (psi) (gal/8troke) (spmlgpm) On 5 8 2,597 2.04 125/255 Surface 3 National Oil A600PT Intermediate Well 5 8 2,597 2.04 125/255 5 8 2,597 2.04 125/255 Production Tabulated below are the expected flow rates, standpipe pressures and nozzle sizes for each hole section. Hokt StandpIpe MIn Nozzle Depth-MD Size Pump Rate Pressure AV ECD Size (It) (in) (cvvn) (psi) ({pm) (lblgaI) (32"8) ~ 0-2,100 16 640 1,600 68 3 - 16's Actual Data from BC #14 (@ 2,130' MD) 1 -18 2,100-7,146 12 1/4 596 2,100 117 3 - 20's Actual Data from Be #14 (@ 7,610' MD) 7,146 - 8,808 81/2 450 1,984 208 5 -15's WellPlan calculations BC #15 (@ 8,808' MD) Comments: See separate hydraulics calculations. Annular velocities in the 16", 121,4", and 8 W' holes were calculated using 5" drillpipe. 5" drillpipe should be used to drill all hole sections to maximize hole cleaning, while minimizing stand pipe pressure. Page 13 of 14 · , Formation Intearitv Test Procedure I Surface and Intermediate casing shoes will be tested to Leak-off. Prior to drilling out of casing strings, test BOPs and casing to the specified pressure listed in the BOP Program section. Plot test and record volume required on the drilling report. Leak-off tests (LOT) are to be conducted as described below: 1. Drill 20' to 25' of new formation below the casing shoe and condition the mud to the same properties in and out. 2. Pull drill string into the casing shoe and close ram preventer, and line up to the choke manifold with a closed choke. 3. Begin slowly pumping fluid down the drill string at 1/2 bpm while recording casing and drillpipe pressures at 1/2 bbl intervals. A running plot of pressure versus volume should be kept by the drilling foreman while the test is in progress. 4. Stop pumping when the pressure curve departs form a straight line sufficiently to indicate leakage into the formation. Record as ppg equivalent mud density in the IADC and morning reports. 5. Monitor and plot pressure drop and time after shut-in for 10 minutes or until the shut-in pressure stabilizes. Page 14 of 14 · 121 1/4" 2M Diverter 1---. Diverter Spool Marathon Oil Well BC #15 Diverter , / I Flow line "> I " / I I / 116" Automatic Knife Valve , ~ e / ,- þ .... .-----------... .;' " \ -- , I I, I í 116" Diverter Line / . Marathon Oil Well BC #15 BOP Stack , I Flow Nipple I . I Flow Line I I 13 5/8" 5M Annular I Preventer .. "> / I I ) < 113 5/8" 5M Double Ram Preventer 121/16" 5M Manually Operated Valves ,~ X X 135/8"5MCross I ~~: .~/ r I~ IC ---. IC I Pipe Ram I ~'L- 121/16" 5M Check Valve \ I Blind Ram I ~ , > I " < I " 13 1/8" 5M Manually I Operated Valve '" Î ŒillJ " "- íl~ 24-45" from ground level for Glacier 1 rig placement. 113 5/8" 5M Tubing Head Flange f3 1/8" 5M Hydraulically I Operated Valve 1135/8" 5M x 13 5/8" 5M Drilling Spool Bottom of mud cross must be · , Marathon Oil Well BC #15 Choke Manifold / ITO Gas Buster ITO Blooey Line I OJ t::::j t [ OJ B ~ ~ ~º 13~ va(.. I ~ r: I Bleed off Line to Shakers [0 ~ ~ .1 " 2 9/16" 10M Swaco Hydraulically Operated Choke IFrom BOP Stack r i 13 1/8" 5M Manually Adjustable Choke · , Surface Use Plan for Beaver Creek #15 Surface location: Anticipated at 91 ft FSL, 1,443 ft FEL, Sec. 33, T7N, R10W, S.M. 1) Existing Roads Existing roads, which will be used for access to Beaver Creek #15, are shown on the attached map. Kenai, Alaska is the nearest town to the site and is shown on the map. 2) Access Roads to be Constructed or Reconstructed No new roads will be required to access BC #15. 3) Location of existing wells Well BC #15 will be drilled on pad BC 1 A A pad drawing is enclosed that shows existing wells and the proposed location of BC #15. 4) Location of existing and/or proposed facilities The locations of existing production facilities are shown on the enclosed pad drawing. The BC #15 will use the existing production facilities and will require only the addition of a new flow line, line heater, separator skid, and meter. 5) Location of Water Supply A water supply well exists on the pad that BC #15 will be drilled from. This is shown on the pad drawing. 6) Construction Materials No construction is planned on the pad. 7) Methods of handling waste disposal; a) Mud and Cuttings Cuttings will be dewatered on location. The cuttings and excess mud will be hauled to Pad 41-18 of the Kenai Gas Field for disposal into Well KU 24-7. a Class" disposal well (AOGCC Disposal Injection Order No.9, Permit #81-176). b) Garbage All household and approved industrial garbage will be hauled to the Kenai Peninsula Borough Soldotna Landfill. c) Completion Fluids Clear fluids will be injected into approved disposal wells Beaver Creek # 2 (Alaska Oil / and Gas Conservation Commission Disposal Injection Order No.4) or hauled to Pad 34- 31 of the Kenai Gas field and injected in Well WD #1, an approved disposal well (AOGCC Permit #7-194). · , d) Chemicals Unused chemicals will be returned to the vendors that provided them. Efforts will be made to minimize the use of all chemicals. e) Sewage Sewage and wastewater will be collected in steel holding tanks and hauled to a Kenai sanitation facility for disposal. 8) Ancillary Facilities A minimal camp will be established on the pad to house various supervisory and service company personnel. Approximately four trailer house type structures will be required for this purpose. Bottled water will be used for human consumption. Potable water will be obtained from the existing water well on the pad. Sand R will collect and transport sanitary wastes to their ADEC approved disposal facility. 9) Plans for reclamation of the surface BC #15 will be drilled from an existing pad. Reclamation of the pad will occur after the abandonment of BC #15 and the other existing wells on the pad. Approval of the plan of reclamation will be obtained from the U.S. Fish and Wildlife Service before any reclamation work beginning. 10) Surface ownership The surface owner of the land in the Beaver Creek Unit is the U.S. Fish and Wildlife Service. The minerals are under the jurisdiction of the U.S. Bureau of Land Management. 11) Operator's Representative and Certification I hereby certify that J, or persons under my direct supervision, have inspected the proposed drill site and access route; that I am familiar with the conditions that currently exist; that the statements made in this plan are, to the best of my knowledge, true and correct; and that the work associated with operations proposed herein will be performed by Marathon Oil Company and its contractors and subcontractors in conformity with this plan and the terms and conditions under which it is approved. This statement is subject to the provisions of 18 U.S.C. 1001 for the filing of a false statement. 9!ZZ/¿Lf Name and Title: :J¡~iil/1/J ~~,'}v/t~ Willard J. TanJç., Advanced Senior Drilling Engineer Marathon Oil Company P. O. Box 3128 Houston, TX 77253 (713) 296-3273 Date: COMPRES$ION r ELECTRiCAl / B~LC¡NG DE:':s.'i:''¡;OO 'I if, í !;;"~~PO" .~ Jt::::. £::::Jj LINE HEATER r&--- 25,2')( 8.5' GAS COMPRESSOR COMPRES~~ '---J COOLER aU/WING BUILDING >10 . 1O<fS~::;:"D BCU NO. 1A WELL SlUG~~~ .r--;;..... WAiERTANK CON~,,~~~~1~: 14.8' DIA. WELL HOUSE ~ ---.:.:: ~,32.6')(11,1' E"'31442069""""'\. ~~ iÞ 10< ... '- T.P,", (CEV."'" '\, N = 2430086,36 \¥ .. " " 8U"0'''".... \.... LUM NAIRE9(r:PI~) METHANOL TANI< O'GE = 314428.19 WASTEWATER BCU NO. 14 WELLe ... ELEV = 141,2 '~~L~:; , AS BUILT ~ 1443' FEL 0 0 n/ I BEAVER CREEK NO. 15 ..J ~ 6;~' ff GRID N:2430050.486 æ PAD 1 A 12,WATERTAtlKS E GRID E:314312.737 _ 12.,P,A I LATITUDE: 60°38'50,945" N 0; ~ LONGITUDE: 151°02'04.806" N ! ELEV.141' ~ Consulting c;roup ucLane Testing IV' I 'DAlE OF'SURVEY:8/28/04 No, DAlE BY APP. 'BOO ( NO.: N/A TE~ 9C7.2S3.421 S FAX 9C7.2S3.3265 )'RO£CT NO.: 033089 DRAIIING NO.: D33089 SCALE ,..,00' DRAWN BY: MSM . "",\\\., ...' OF At.. 'f ~ '\~""'''''....-1 f. - ,,~.., ~"~1:: ~I 3' *~:49 Il:l 'AT '..y *~ ",................................... , ~ ~ ,................................... ", ~ ~ ". M. SCOTT McLANE ,: I! .- ,0,.. . - " \II~... 4928-S .... - ;''): " .'- ~ .... .... - I 'ð A...... ...... \..Ø'... t. . 'rtlFtSSIOtl~\.. ,'" ,\\\"", P.O. Box 46B 60L.DOTNA. AK 99669 GRID , r --- l / ~ / , I T7N R10W T6N 8M AK 33 34 4 3 ~ CLEARING LIMITS l' T ' ' 1'''', r l' ' ' l' 1 . . r r l' r Y""'r'" ....,.....( WETLANDS Ir ~ SURVEY NOTES 1, BASIS OF HORIZONTAL COORDINATES IS NGS STATION AUDRY, NAD27 ALASKA ST ATE PLANE ZONE 4, 2. BASIS OF VERTICAL CONTROL IS NGS MONUMENT D81 (NAVD 88). 3, OFFSETS TO SECTION LINE DETERMINED FROM TIES TO BLM SECTION CORNERS FOUND ALONG THE SOUTH BOUNDARY OF THE TOWNSHIP FOUND THIS SURVEY, o I SCALE 1" = 100' 100 I FEET ~ 200 I ~ RE\iISIDNS ~ Marathon \ ~~:) Oil Company . Alaska Reqlon ENGINEER APPROVAl. BY DAlE SEA VER CREEK UNIT KENAI, ALASKA BEAVER CREEK NO. 15 WELL AS-BUILT SURFACE LOCATION DIAGRAM PRO.£CT S1RUCT. PIIOÇES$ MECHAN. ELECT. INS1R\JM. AAQoI. FatS SCAl£ DWN. __ DAlE 5/1""" CHKP. DAlE ,··,00' APP." _ (¡AlE APP. .. r_ DAlE AlE NO. 'NPE ORG MOD DISC SYST BC3 SOOO 000 DWG NO. SlIT NO, REV 0D01 0 VICINITY MAP o 1ß4f;?2;J0.gf¡}ìøh 8000 {à{li£fi:l(ft[£Î¡¥!$P Scale in Feet \ , N Marathon Oil Company Road \ ~~'i""" ~ç,'(". <fj9~~ ...0 »"''11 '\'\ ~ K' PURPOSE: New Development Gas Well BCU No. 15 ADJACENT PROPERTY Kenai National Wildlife Refuge -- j N 4 AT: IN: - e ll; ~ I 1 l , þ ¡ K I , If: f! I ~ ~ /..-- ~3 t~ > ~\ T ~. , . \ BCU--15 ~ '" I ...... \ - 1'-11' ........ I I L________ I I I I I I I , I t .........-....., I ~\ :1EGASSER} " I 1'......_....., I . .. ~-----1 ~-----{ ro- t L__...I II : I I t t ,.--, 11 I , r I I, r I I I II I I r . [ II I I ¡I' I II I I I II I I I II I I I II I I I ,., .. \1 I I t I b I 'I II I L:....__J '------J I ï- ;----;ì I I I -," _..' I I l- I J .; , I r------, I I b:NTRIR&:! I UNIT I I 4' ( 10' I I I I I I I I I I DtJIP I - I l) I I I L.__.___.1 KtDfY 3' X 12' J'}\IIUII 7511' 6X5 11· c L....---t ~... t rr. ; t ... .... , ... .. .. re '- . .~ ...1IIIIM \. 7':iJP 6)(5 11' ~ 75 HP '6 Ie :5 II' L.-- :-; _..i .. ., . " .. , ,. .. 1,.::;. . GLACIER DRILLING RIG #1 ........ MUD PITS AND PUMP ROOM LAYOUT -~'r !l 0 .... IF 5V 91.. woo PT 15", 61<' 11' - ;' p,t . I .. ~ 't .. . . . !o l..::'. , . . 'ië1 ioJ !€ ... ·z 5V 91- A-600 PT ~. '%' -- œ . t ~..". . . .... PI.\. IV E:3 w.... . m..~ m._~ 17.... e ~ f"'iiiiì ~ ~.~ '&ií. BAKER IIUGIIES INTEQ . . MARATHON Oil Company _._---_.----~ Location: Kenai Peninsula, Alaska Slot: Slot #15 Field: Beaver Creek Unit Well: BC-15 Installation: BC Pad 1A Well bore: BC-15 Ver 1 M MARATHON ¢:: 0 -500 It) N II 5 0 ..... C ) ëii () C/) 500 1000 1500 2000 2500 3000 - - Q) Q) ::. 3500 .c - Q. Q) 4000 Q C'CI CJ 4500 1:= ~ 5000 Q) :J '- t- I 5500 V 6000 6500 7000 7500 8000 f Scale 1 cm = 100 ft -200 0 200 East (feet) -> 400 600 800 1000 1200 1400 1600 I.~I l 600 400 {¡> ~. ~ 0- i$)\!!. ~ ^ I ..r <2.9 (\ ~ 07.~. /6' ~ is'~ ' C '(<2~ . v~ i$)d)~ \9¿ íS}~ :J..Q í9 ~~ í9 ~&+ (~ '~ - ló' \?a , ~ ~ % ;r Z 200 0 I o m J j L 13 3/8in Casing 3DS Kick off Point - 0.00 inc, 2300.00 Md, 2300.00 Tvd, 0.00 VS 4.00 8.00 DLS: 2.00 deg/100ft II -200 0 o ;::II ~--- WELL PROFILE DATA Point ~-~ 1VD ~OrthrEast I deg/100ft V.Sect Tie on 0.00 0,00 0.00 0.00 0.00 0,00 0.00 0.00 KOP 2300.00 0.00 0.00 2300.00 0.00 0,00 0.00 0.00 End of BuildlTum 2943.86 12.88 82.72 2938.45 9.14 71.47 2.00 72,03 End of Hold 6873.12 12.88 82.72 6788.89 120.13 940.09 0.00 947.54 Target BC15 - L Beluga 7170.83 7.02 89.10 7062.00 124,63 991.23 2.00 998.86 T.e, & Target BC15 - U 8808.09/ 7.02 89.10 8887.00 127.78 1191,21 0.00 1198.05 9 5/8in Casing End of Hold - 12.88 Inc, 6873.12 Md, 6768.89 Tvd, 947.54 VS l 8.40 BC15 - L Beluga LB-15 - 8/30/04 8500 BC15 - U Tyonek - 8/30/04 3 1/2in Casing 9000 -500 -0 500 1000 1500 2000 Created by: Planner Dale plotted: 3o-Aug-2004 Plot reference is BC-15 Ver 1, Ref wellpath is BC-15 Ver 1. Coordinates are in feet reference Slot #15, True Vertical Depths are reference Rig Datum. Measured Depths ere reference Rig Datum. I Rig Datum: Datum #1 Rig Datum to mean sea level: 162.00 ft. Plot North is aligned to TRUe North, Scale 1 em = 250 ft 9500 Vertical Section (feet) -> Azimuth 83.88 with reference 0.00 N, 0.00 E from Slot #15 , 0 ,M ~MARATHON ~y Name BC-15 Ver 1 ..' Name BC-15 iii;·;·' Name Slot #15 . . MARATHON Oil Company,Slot #15 BC Pad 1A, Beaver Creek Unit, Kenai Peninsula, Alaska PROPOSAL LISTING Page 1 Wellbore: BC-15 Ver 1 Wellpath: BC-15 Ver 1 Date Printed: 30-Aug-2004 .1. .,... INTEQ I Last Revised 30-Aua-2004 -.lCreated ~Aua-2004 --~-- I Govemment ID I Last Revised 30-Aua-2004 I Grid NOrthina 2430050.4860 Lonaitude W151 24.8065 I Grid Eastina 314312.7370 I Latitude N60 38 50.9447 Name Be Pad 1A I Northina I Coord SYStem Name 321035.295L~~~ 2429855.724lAK-4 on NORTH AMERICAN DATUM 1927 -",..y,.. " " " ~' '0 . .. '6-- Name Beaver Creek Unit I Coord SYStem Name 2429855.7244 AK-4 on NORTH AMERICAN DATUM 1927 I Eastino J Northina 321035.295 -~~-~-----_.,--~--------_._~. -~._~ All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Datum #1 162.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 83.88 degrees Bottom hole distance is 1198.05 Feet on azimuth 83.88 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . . , M MARATHON J MARATHON Oil Company,Slot #15 BC Pad 1A, Beaver Creek Unit,Kenai Peninsula, Alaska PROPOSAL LISTING Page 2 Wellbore: BC-15 Ver 1 Well path: BC-15 Ver 1 Date Printed: 30-Aug-2004 8.. ...,. INTEQ _í'._1~'·· . ...., .. .... . .., ", .'. MP(ft] lno[deg] Azi[deg] TVP[ft] NoI1h[ft] East(ft] Vertical Sectionfftl 0.00 0.00 0.00 0.00 O.OON O.OOE 0.00 0.00 314312.7' 2430050.4£ 100.00 0.00 0.00 100.00 O.OON O.OOE 0.00 0.00 314312.7' 2430050.4! 200.00 0.00 0.00 200.00 O.OON ~-~- O.OOE 0,00 0.00 314312.7' 2430050.4! 300.00 0.00 0.00 300.00 O.OON --- O.OOE 0.00 0.00 314312.7' 2430050.4£ 400.00 0.00 0.00 400.00 O.OON O.OOE 0.00 0.00 314312.7' 2430050.4! 500.00 0.00 0.00 500.00 O.OON O.OOE 0.00 0.00 314312.7' 2430050.4! 600.00 0.00 0.00 600.00 O.OON O.OOE 0.00 0.00 314312.7' 2430050.4£ 700.00 0.00 0.00 700.00 O.OON O.OOE 0.00 0.00 314312.7' 2430050.4! 800.00 0.00 0.00 800.00 O.OON O.OOE 0.00 0.00 314312.7' 2430050.4£ 900.00 0.00 0.00 900.00 O.OON O.OOE 0.00 0.00 314312.7' 2430050.4£ _ 1000.0' 0.00 0.00 1000.0C O.OON O.OOE 0.00 0.00 314312.7' 2430050.4£ 1100.0' 0.00 0.00 1100.0' O.OON O.OOE 0.00 0.00 314312.7' 2430050.4! 1200.0' 0.00 0.00 1200.0C O.OON O.OOE 0.00 0.00 314312.7' 2430050.4£ 1300.0' 0.00 0.00 1300.0C O.OON O.OOE 0.00 0.00 314312.7' 2430050.4! 1400.0' 0,00 0.00 _ 1400.0' o.oON O.OOE 0.00 0.00 314312.7' 2430050.4£ 1500.0' 0.00 0.00 1500.0C O.OON O.OOE 0.00 0.00 -- 314312.7' 2430050.4£ __ 1600.0' 0.00 0.00 1600.0C O.OON O.OOE --~ 0.00 314312.7' 2430050.4£ 1700.0C 0.00 0.00 1700.0C O.OON O.OOE 0.00 0.00 314312.7' 2430050.4£ 1800.0C 0.00 0.00 1800.0C O.OON O.OOE 0.00 0.00 314312.7' 2430050.4! 1900.0' 0.00 0.00 1900.0C O.OON O.OOE 0.00 0.00 314312.7' 2430050.4! 2000.0C 0.00 0.00 2000.0' O.OON __---º.OOE 0.00 0.00 314312.7' 2430050.4£ 2100.0' 0.00 0.00 2100.0' O.OON O.OOE 0.00 0.00 314312.7' 2430050.4£ 2200.0' 0.00 0.00 2200.0' O.OON O.OOE 0.00 0.00 314312.7' 2430050.4£ 2300.0' 0,00 0.00 2300.0' O.OON O.OOE 0.00 0.00 314312.7' 2430050.4£ 2400.0<: 2.00 82.72 2399.9E, 0.22N 1.73E 2.00 1.74 314314.4i 2430050.61 2500.0C 4.00 82.72 2499.84 0.89N 6.92E 2.00 6.98 314319.6i 2430051.2E 2600.0C 6.00 82.72 2599.45 1.99N 15.57E 2.00 15.69 314328.3~ 2430052.2~ 2700.0C 8.00 82.72 2698.7L 3.53N 27.66~___~_ 27.87 314340.4' 2430053.51 2800.0C 10.00 82.72 2797.47 5.52N 43.17E 2.00 43.51 314355.9£ 2430055.3: 2900.0' 12.00 82.72 2895.62 7.93N 62.10E 2.00 62.59 314374.9f 2430057.4' 2943.86 12.88 82.72 2938.45 9.14N 71.47E 2.00 72.03 314384.3.1 2430058.5( 3000.0' 12.88 82.72 2993.1E, 10.72N 83.88E 0.00 84.54 314396.7i 2430059.8£ 3100.0<: 12.88 82.72 3090.66 13.55N 105.99E 0.00 106.83 314418.9. 2430062.3E 3200.0C 12.88 82.72 3188.15 16.37N 128.09E 0.00 129.11 314441.0E 2430064.8' 3300.0C 12.88 82.72 3285.6::' 19.20N 150.20E 0.00 151.39 314463.2' 2430067.3' 3400.0C 12.88 82.72 338;3,12 22.02N 172.31E -,-º,ºº--- 173.67 314485.3..L__ 2430069.1£ 3500.0' 12.88 82.72 3480.6<: 24.85N 194.41E 0.00 195.95 314507.5C 2430072.2; 3600.0' 12.88 82.72 3578.0~ 27.67N 216.52E 0.00 218.23 314529.6f 2430074.7' 3700.0<: 12.88 82.72 3675.57 30.50N 238.63E 0.00 240.52 314551.8C 2430077.2: 3800.0<: 12.88 82.72 3773.06 33.32N 260.73E. 0.00 262.80 314573.9' 2430079.7( 3900.0C 12.88 82.72 3870.54 36.15N 282.84E 0.00 285.08 314596.0£ 2430082.1 ; 4000.0C 12.88 82.72 3968.0::' 38.97N 304.94E 0.00 307.36 314618.2' 2430084.6~ 4100.0C 12.88 82.72 4065.51 41.80N 327,05E 0.00 329.64 314640.3£ 2430087.1, 4200.0C 12.88 82.72 4163.0( 44.62N 349.16E ~ 351.92 314662.5~ 2430089.6~ 4300.0' 12.88 82.72 4260.4E, __47.45N 371.26E 0.00 374.21 314684.6£ 2430092.01 4400.0<: 12.88 82.72 4357.97 50.27N 393.37E -º'ºº--- 396.49 314706.8~ 2430094.5E 4500.0<: 12.88 82.72 4455.45 53.09N 415.48E 0.00 418.77 314728.9i 2430097.0: 4600.0<: 12.88 82.72 4552.94 55.92N 437.58E 0.00 441.05 314751.1. 2430099.5~ 4700.0G 12.88 82.72 ..----4650.42 58.74N 459.69E 0.00 463.33 314773.2i 2430101.9~ 4800.0C 12.88 82.72 4747.91 61.57N 481.80E 0.00 485.62 314795.4' 2430104.4E 4900.0C 12,88 82.72 4845.3E 64.39N 503.90E _ 0.00 507.90 314817.5E 2430106.9' All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig (Datum #1162.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 83.88 degrees Bottom hole distance is 1198.05 Feet on azimuth 83.88 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . . , M MARATHON ~ MARATHON Oil Company,Slot #15 BC Pad 1A, Beaver Creek Unit,Kenai Peninsula, Alaska PROPOSAL LISTING Page 3 Wellbore: BC-15 Ver 1 Wellpath: BC-15 Ver 1 Date Printed: 30-Aug-2004 .¡. 'WI.. INTEQ MO[ft] Inc{deo] ~~] TVD[ft) North[ft] East[ft] Dogleg Idea/100m 50OO.0C 12.88 82.72 4942.88 67.22N 526.01E 314839.7' 2430109.4' 5100.0(, 12.88 82.72 5040.36 70.04N 548.12E 0.00 552.46 314861.8f 2430111.8~ 5200.~ 12.88 82.72 5137.85 72.87N 570.22E 0.00 574.74 314884.0C 2430114.3, 5300.0 12.88 82.72 5235.3~ 75.69N 592.33E 0.00 597.02 314906.H 2430116.8< 5400. 12.88 82.72 5332.82 78.52N 614.44E 0.00 619.31 314928.2e 2430119.3~ 5500.0(, 12.88 82.72 5430.3c' 81.34N 636.54E 0.00 641.59 314950.4< 2430121.8C 5600.0(, 12.88 82.72 5527. 7~ 84.17N 658.65E 0.00 663.87 314972.5e 2430124.2, 5700.0(, 12.88 82.72 5625.2 86.99N 680.76E 0.00 686.15 314994.7~ 2430126.7! 58oo.OC 12.88 82.72 5722.7 89.82N 702.86E 0.00 708.43 315016.8E 2430129.2: 5900.0C, 12.88 82.72 5820.2{ 92.64N 724.97E 0.00 730.71 315039.0~ 2430131.7C 6000.0C 12.88 82.72 5917.7:: 95.47N 747.08E 0.00 753.00 315061.1E 2430134.11 6100.OC 12.88 82.72 6015.21 98.29N 769.18E 0.001 775.28 315083.3~ 2430136.6! 6200.0(, 12.88 82.72 6112.7C 101.12 791.29E 0.00 797.56 315105.47 2430139.1~ 6300.0(, 12.88 82.Z2-~210.1f 103.94N 813.39E 0.00 819.84 315127.6~ 2430141.6' _ 6400.0(, 12.88 82.72 6307.67 106.77N 835.50E 0.00 842.12 315149.1£ 2430144.01 6500.0C 12.88 82.72 6405. ~__t09.59N 857.61E 0.00 864.41 315171.9' 2430146.51 6600.0(, 12.88 82.72 6502.64 112.42N 879.72~ 0.00 886.69 315194.0€ 2430149.().<' 6700.0C, 12.88 82.72 6600.12 115.24N 901.82E 0.00 908.97 315216.2C 2430151.5' 6800.0C 12.88 82.72 6697.61 _JJ8.07N 923.93E 0.00 931.25 315238.3f 2430153.9~ 6873.12 12.88 82.72 6768.8£ 120.13N 940.09E 0.00 947.54 315254.5< 2430155.8( 6900.0(, 12ffi 83.05 6795.12 120.86Nj 945.92E 2.0 953.41 315260.3E 2~1~1 7000.0q 10.3 84.56 6893.16 123.01N 965.49E 2.00 973.10 315279.9E 2430158.2 7100.0C 8.40 86.78 6991.81 124.27N 981.74E 2.00 989.39 315296.2f 2430159.2 7170.8~ 7.02 89.10 7062.OC 124.63N 991.23E 2.00 998.86 315305.7< 2430159.4 7200.0(, 7.02 89.10 7090.95 124.68N 994.79E 0.00 1002.41 315309.3C 2430159.4f 7300.0C 7.02 89.10 7190.21 124.88N 1007.01E 0.00 1014.5€ 315321.5~ 2430159.4~ 7400.0C, 7.02 89.10 7289.4 125.07 1019.22E 0.00 1026.7E 315333.7:: 2430159.4f 7500.OC -~-- 89.10 7388.7 125.26 1031.43E 0.00 1038.91 315345.9f 2430159.4~ 7600.0C 7.02 89.10 7487.9 125.45N _~3.65E 0.00 1051.0 315358.1i 2430159.4~ 7700.0C 7.02 89.10 7587.21 125.65N 1055.86E 0.00 1063.2< 315370.3€ 2430159.4f 7800.0C 7.02 89.10 7686.4 125.84N 1068.08E 0.00 1075.41 315382.6C 2430159.4~ 7900.OC 7.02 89.10 7785.71 126.03N 1080.29E 0.00 1087.57 315394.8' 2430159.4~ 8000.0(, 7.02 89.10 7884.9 126.22N 1092.51E 0.00 1099.7< 315407.0~ 2430159.4~ 8100.0( 7.02 89.10 7984.21 126.42N __JJQ4.72E 0.00 1111.9C _~15419.2< 2430159.4~ 8200.0( 7.02 89.10 8083.47 126.61N 1116.94E 0.00 1124.07 315431.4€ 2430159.4~ _ 8300.0C 7.02 89.10 8182.72 126.80N 1129.15E 0.00 1136.2< 315443.6i 2430159.4~ 8400.0C 7.02 89.10 8281.97 126'99~ 114137' 0.00 1148.4(, 315455.8€ 2430159.4~ 8500.0(, 7.02 89.10 8381.22 127.18 1153.58E 0.00 1160.57 315468.1' 2430159.4~ 8600.0C 7.02 89.10 8480.47 127.38N 1165.80E 0.00 1172.7:: 315480.3~ 2430159.4~ 8700.0(, 7.02 89.10 8579.72 127.57 1178.01E 0.00 1184.9C 315492.5< 2430159.4~ 8800.0~ 7.02 89.10 8678.9~ 127.76 ~1190.23E 0.001 1197.06 315504.n 2430159.4~ 8808.0 7.02 89.10 8687.0 127.78 1191.21E 0.00 1198.05 315505.7< 2430159.4~ All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig (Datum #1 162.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 83.88 degrees Bottom hole distance is 1198.05 Feet on azimuth 83.88 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . . ,. 1 M MARATHON ¡ MARATHON Oil Company,Slot#15 BC Pad 1A, Beaver Creek Unit, Kenai Peninsula, Alaska PROPOSAL LISTING Page 4 Wellbore: BC-15 Ver 1 Wellpath: BC-15 Ver 1 Date Printed: 30-Aug-2004 ... "III.s INTEQ StÆlrt MDlft1 16.000 12 1/4 81/2 TV00t1 0.00 2100.0C. 7145.62 StÆlrt StÆlrt End End Northfft1 ~1fft1 MDlft1 TVDfft1 0.00 O.OON O.OOE 2100.0C 2100. 2100.0c. O.OON O.OOE 7145.62 7037.0 7037.~ 124.55N 988.04E 8808.02 8687. Start Nørthfft1 Eastfft1 O.OON O.OOE BC-15 Ver 1 124.55N 988.04E BC-15 Ver 1 127.78N 1191.21EBC-15Ver1 N$me Top Top Top Top Shoe Shoe Shoe MDrfU TVDrft1 Northrftl Eastlftl MDrttl TVDrftl Northrffl E8$tlft1 13 3/8in Casina 0.00 0.00 O.OON O.OOE 2100.0C. 2100.0c. O.OON O.OOE BC-15 Ver 1 9 5/8in Casina 0.00 0.00 O.OON O.OOE 7145.62 7037.0C. 124.55N 988.04E BC-15 Ver 1 3 1/2in Casino 0.00 0.00 O.OON O.OOE 8808.0S 8687.0C 127.78N 1191.21E BC-15 Ver 1 124.63N Lonaitude Eastina 3852.1i W151 1 44.9 Norhtina 315305.7< 2430159.4 Náme' BC15 -l Beluga lB-15 - 8/30/04 BC15 - U Tyonek- 8/30/04 14-Apr-2003 127.78N 1191.21E 38 52.2( W151 1 40.9 315505.7< 2430159.4 14-Apr-2003 All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig (Oatum #1162.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 83.88 degrees Bottom hole distance is 1198.05 Feet on azimuth 83.88 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated 900 1 400 - - C!) .! 300 - J: 1::: ~ 200 ¢:: -200 E u ( ) ~ -300 ø Created by: Planner Date plotted: 3O-Aug.-2004 Plot reference is BC~15 Var 1, ,-,,-~~- - Refwellpath is BC-iS Ver 1. Coordinates are in feet reference Slot #15, True Vertical DepthS are reference Rig Datum. Measured Depth$ are reference Rig Datum. Rig Datum: Datum #1 Rig Datum to mean- sea level: 162.00 ft. Plot North is aligned to TRUE North. EJlipse dimensions are of PROJECTED error eUìpsoid ~1,¡¡~~_~~~_~--,~__~~~~t?_~?~~~_!~~~~~~,~~_~____ MARATHON Oil Company location: Kenai Peninsula, Alaska Slot: Slot #15 Field: Beaver Creek Unit Well: BC-15 Installation: BC Pad 1A Wellbore: BC-15 lIer 1 Scale 1 em ::: 50 ft East (feet) .> -200 -100 200 500 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 300 600 700 400 o 100 800 4200 4100 4000 700 600 3900 3800 500 3700 'S1'; 6Q ý'ó! 1900 Vo Do ý'r; 00 ~ DO ý'û! Vo ý'~ DO ý'ó; Vo ý'óJ DO ý'> 00 100 o -100 o 200 400 600 700 800 900 1000 1100 1200 East (feet)-> 300 500 6")'; 00 1400 ~ Do 6"û! DO 6"1<': DO 6"ó; DO 6"> ~ 00 Vo 1600 1700 1800 1900 900 800 700 600 500 400 ^ . z 0 300 :t :::r - 200 100 -0 -100 (f) ~ (¡) -200 (') 3 " -300 01 <::> ;::: > any AHA THON Oil Co Date plotted: 30-Aug-2004 Plot relerence is sc:.15 VerT·~~· Relwallpath is BC-15 Var 1, Coordinates are in feet reference Slot #15. True Vertical Depths are reference Rig Datum, Measured Depths are reference Rig Datum. Rig Datum: Datum #1 ;~~t~:;~aI~~;s~a~;~~:~:;;o It .1 location: Kenai Peninsula, Alaska Slot: Siot #15 Field: Beaver Creek Unit Well: BC-1S Installation: BC Pad 1A Wellbore: BC-1S Ver 1 TRUE NORTH 350 o 280 290 270 260 250 200 160 190 170 180 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths ~ 90 100 . . , M MARATHON MARATHON Oil Company BC-15 Ver 1, BC-15 Ver 1 Slot #15, BC Pad 1A CLEARANCE LISTING Page 1 Date Printed: 30-Aug-2004 Beaver Creek Unit, Kenai Peninsula, Alaska ... ~ INTEQ Ellipse separations are reported ONLY if BOTH wells have uncertainty data Only Depth and Ma ;¡netic Reference Field error terms are correlated across tie points Proximities beyond ft with expansion rat~ of ft/1 OOOft are not reported Cutoff is calculated on CENTRE to CENTRE distance Summary data uses Closest Approach clearance calculation for all minima Hole size/CasinQs are NOT included Hole size/CasinQs are NOT subtracted from Centre-Centre distance Ellipses scaled to 2.00standard deviations. ClosinQ Factor Confidence limit of 99.80% Errors on Ref start at Slot Permanent Datum (0.00) Report uses Revised: (D-C)/E Factor Calculation Name BC-15 Ver 1 ¡ J Created . . 30-Aua-2004 ~-----_.- BC-15 ID N60 38 50.9447 W151 24.8065 J Northioa 321035.295 . SYStem Name AK-4 on NORTH AMERICAN DATUM 1927 Name Be Pad 1A Name Beaver Creek Unit I Northina 321035.29~ J Coord SYStem Name 2429855.724 AK-4 on NORTH AMERICAN DATUM 1927 Offset WeUName ~t~.~WtW Offset Offset Wellbore Slot Offset Structure Minimum Distance fft1 MO[ft] Diverging From(ft] Ellipse Separation fft1 1611.75 9.00 Ellipse MO[ft] BC-14 1A BC-14 BC-1A Slot #14 Slot #1A Be Pad 1A _ Be Pad 1A 53.42 120.91 __1611.75 _ 9.00 48.03 120.86 1722.4i 9.00 8.17 34.86 2263.7S 3428.4E ~~(Iiì"'W___ Survey Name MOffU I Survey Tool Planned 8808.0a Navi Trak I Error MOdel Saa and MaQ Corrected All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig (Datum #1 162.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (1 D) Prepared by Baker Hughes Incorporated . . , M MARATHON ~ ~ MARATHON Oil Company BC-15 Ver 1, BC-15 Ver 1 Slot #15, BC Pad 1 A CLEARANCE LISTING Page 2 Date Printed: 30-Aug-2004 Beaver Creek Unit, Kenai Peninsula, Alaska .1. --=- INTEQ R,ference Reference Reference Reference Offset Offset Offset Angle MOEft] TVDEft] NorthEft] East[ft] MO[ft] TVOEft] NorthEft] East[ft) From Highslde fdeat rftt 0.00 0.00 O.OON O.OOE BC-14 --~~ 0.00 0.00 21.75N 55.12E _ 68.5 59.26 59.26 16.40 16.40 O.OON O.OOE BC-14 16.29 16.29 21.74N 55.16E 68.5 59.29 59.13 100.00 100.00 O.OON O.OOE BC-14 99.65 99.65 21.72N 55.41E 68.6 59.52 59.13 200.00 200.00 O.OON O.OOE BC-14 200.13 200.12 21.59N 55.96E 68.9 59.98 59.30 300.00 300.00 O.OON O.OOE BC-14 300.15 300.15 21.25N 55.86E 69.2 59.77 58.74 400.00 400.00 O.OON O.OOE BC-14 400.15 400.14 20.83N 55.75E 69.5 59.52 58.16 500.00 500.00 O.OON O.OOE BC-14 500.22 500.22 20.20N 55.67E. 70.1 59.22 57.52 600.00 600.00 O.OON O.OOE BC-14 600.28 600.27 19.33N 55.55E 70.8 58.82 56.77 700.00 700.00 O.OON O.OOE BC-14 700.39 700.37 18.08N 55.38E 71.9 58.26 55.87 800.00 800.00 O.OON O.OOE BC-14 800.43 800.41 16.71N 55.12E 73.1 57.59 54.87 900.00 900.00 O.OON O.OOE BC-14 900.42 900.38 15.03N 54.88E. 74.7 56.90 53.88 1000.0C 1000.0C O.OON O.OOE BC-1~__ 1 000.4~ 1000.36 12.81N 54.78E 76.8 56.26 52.95 1100.0<: 1100.0C O.OON O.OOE BC-14 1100.47 1100,37 10.19N 54.66E 79.4 55.61 52.00 1200.0C 1200.0C O.OON O.OOE BC-1~ 12oo.4¿ 1200.3(, 7.29N 54.49E 82.4 54.98 51.07 1300.0C 13oo.0C O.OON O.OOE BC-14 1300.3< 1300.16 4.53N 54.37E 85.2 54.56 50.33 1400.0C 1400.0C O.OON O.OOE BC-14 1400.3< 1400.14 3.09N 54.22E 86.7 54.31 49.73 1500.0C 1500.0C O.OON O.OOE BC-14 __~ 1500.51 _1P00.31 2.89N 53.71E 86.9 53.79 48.89 1600.0<: 1600.0C O.OON O.OOE BC-14 1600.21\ 1600.07 4.10N 53.27E 85.6 53.43 48.24 1611.7~ 1611.7E O.OON O.OOE BC-14 1612.0C 1611.7~ 4.33N 53.24E 85.3 53.42 48.19 1700.0C 1700.01; O.OON O.OOE BC-14 1700.1e 1699.86 6.32N 53.15E 83.2 53.53 48.04 1722.44 1722.4< O.OON O.OOE BC-14 1722.5~ 1722.2E 6.83N 53.15E 82.7 53.58 48.03 1800.0C 1800.0C O.OON O.OOE BC-14 1799.9E- 1799.72 8.61N 53.19E. 80.8 53.89 48.11 1900.0<: 1900.0C O.OON O.OOE BC-14 1899.91 1899.62 11.02N 53.36E 78.3 54.48 48.42 2000.0<: 2000.0C O.OON O.OOE BC-14 1999.82 1999.5C 13.45N 53.60E 75.9 55.27 48.90 2100.0C 2100.0C O.OON O.OOE BC-14 2099.8e 2099.45 15.86N 53.92E 73.6 56.21 49.55 2200.0C 2200.0C O.OON O.OOE BC-14 2199.71 2199.3~ 18.34N 54.15E. 71.3 57.18 50.23 2263.7€ 2263.7€ O.OON O.OOE BC-14 ___ 2262.n 2262.3C 20.84N 54.45E 69.1 58.32 51.18 2300.0(, 2300.0C O.OON O.OOE BC-14 2298.11 2297.62 22.92N 54.80E 67.3 59.45 52.19 24oo.0C 2399.9~ 0.22N 1.73E BC-14 _~_ 2395.31 2394.35 31.99N 56.98E -22.6 63.97 56.43 2500.0C 2499.8¿ 0.89N 6.92E BC-14 2489.1B 2486.92 46.64N 61.83E -32.2 72.63 64.73 2600.0<: 2599.4S 1.99N 15.57E BC-14 2584.02 2579.42 65.11N 71.54E -40.4 86.70 78.44 2700.0C 2698.7C 3.53N 27.66E BC-14 2681.6C 2674.22 84.19N 84.64E -46.3 101.74 93.14 2800.0<: 2797.47 5.52N 43.17E BC-14 2777.25 2766.8~ 103.67N 98.08E -51.8 116.55 107.57 2900.0C 2895.62 7.93N 62.10E BC-14 2872.8< 2858.8E 125.42N 112.14E -57.3 132.87 123.48 2943.86 2938.4S 9.14N 71.47E BC-14 2914.92 2899.2E 135.50N 118.30E -59.8 140.34 130.75 3000.0<: 2993.1€ 10.72N 83.88E BC-14 2966.32 2948.47 148.60N 125.51E -62.9 150.80 140.94 3100.0C 3090.66 13.55N 105.99E BC-14 3058.3< 3035.97 174.16N 138.00E -67.9 172.66 162.26 3200.0<: 3188.1S 16.37N 128.09E BC-14 3147.2~ 3119.37 201.89N 151.26E -71.5 199.21 188.21 3300.0C 3285.6~ 19.20N 150.20EBC-14 3235.0C 3200.52 231.59N 166.57E -73.7 229.40 217.78 ~-'..."cc/'"cc",·.~_.~", ,:. . "" ,.Rll!t-0'...' ,,-, ," " ,.o' '. "...V t,' :'.. ,c, ,..Ià Well I Wellbore I SUrvevName MOfftt BC-14 BC-14 MWO w/Saa <0-'9361'> All data is in Feet unless otherwise stated Coordinates are from Slot and TVO's are from Rig ( Datum #1162.00 above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (1 D) Prepared by Baker Hughes Incorporated . . r: MARATHON Oil Company BC-15 Ver 1, BC-15 Ver 1 Slot #15, BC Pad 1A CLEARANCE LISTING Page 3 Date Printed: 30-Aug-2004 Beaver Creek Unit, Kenai Peninsula, Alaska ... ..".. INTEQ M MARATHON ~ J Offset Offset Offset MO[ft] TVO[ft] North{ft] High$ide fdElØJ ~ 0.00 0.00 O.OON_ O.OOE 1A__ 0.00 9.00 37.69N 114.88E 71.8 121.24 121.24- 9.00 9.00 O.OON O.OOE 1A _j~~--º.J1L_9.00 37.69N 114.88E 71.8 120.91 120.86 100.00 100.00 O.OON O.OOE 1A 89.84 98.84 38.14N 115.30E 71.7 121.45 121.28 200.00 200.0(, O.OON O.OOE 1A_, 188.9(, 197.88 39.45N 116.51E 71.3 123.03 122.69 300.00 300.00 O.OON O.OOE 1A 289.87 298.84 40.61N 117.54E 70.9 124.36 123.85 400.00 400.00 O.OON O.OOE 1A 390.0E. 399.04 41.23N 118.21E 70.8 125.19 124.51 500.00 500.00 O.OON O.OOE 1A 489.93 498.89 41.22N 119.08E 70.9 126.02 125.11: 600.00 600.00 O.OON O.OOE 1A 589.84 598.79 40.60N 120.26E 71.3 126.94 125.92 700.00 700.00 O.OON O.OOE 1A 689.82 698.75 39.58N 121.62E 72.0 127.90 126.7~ 800.00 800.00 O.OON O.OOE 1A 789.97 798.89 38.45N 122.94E 72.6 128.82 127.46 900.00 900.00 O.OON O.OOE 1A 890.47 899.38 37.10N 123.99E 73.3 129.42 127.89 1000.0e, 1000.0e o.oON O.OOE 1A 990.71 999.61 35.81N 124.77E 74.0 129.80 128.10 1100.0e 1100.0C, O.OON O.OOE 1A 1089.9£. 1098.8E. 34.76N 125.49E 74.5 130.22 128.35 _1200.0e 1200~-------ºÆ>N O.OOE ~__ 1189.77 1198.65 34.20N 126.61E 74.9 131.15 129.11 ~300.0e 1300.0C O.OON O.OOE 1A 1289.9~ 1298.8e 33.58N 127.75E 75.3 132.10 129.89 1400.0(, 1400.0C O.OON O.OOE 1A __1389.86 1398.72 32.93N 128.89E 75.7 133.03 130.65 1500.0C, 1500.0e O.OON O.OOE 1A __M90.3E 1499.24 32.56N 129.78E 75.9 133.81 131.26 1600.0C, 1600.0e O.OON O.OOE 1A 1590.41: 1599.3(, 32.51N 130.35E 76.0 134.34 131.62 1700.0(, 1700.0e O.OON O.OOE 1A 1690.2C 1699.05 32.44N 131.01E 76.1 134.97 132.08 1800.0c' 1800.0C, O.OON O.OOE 1A 1790.2~ 1799.0E 32.30N 131.76E 76.2 135.66 132.60 1900.0e 1900.0e O.OON O.OOE 1A 1890.5< 1899.3E 32.13N 132.46E 76.4 136.30 133.07 2000.0e 2000.0e O.OON O.OOE 1A 1990.5< _i999.3E 31.95N 132.97E 76.5 136.75 133.35 2100.0e 2100.0C O.OON O.OOE 1A 2090.9£. 2099.8~ 31.67N 133.27E 76.6 136.98 133.41 2200.0(, 2200.0e O.OON O.OOE 1A 219M::' 2199.2E. 31.28N 133.63E 76.8 137.25 133.51 2300.0C: 2300.0C O.OON O.OOE 1A 2288.97 2297.81 31.03N 134.63E 77.0 138.18 134.26 2400.0(, 2399.9€ 0.22N 1.73E 1A 2380.9~ 2389.62 33.70N 138.69E -6.4 141.37 137.33 -----2500.0(, 2499.8< 0.89N 6.92E 1A 2469.91 2477.8E 40.77N 147.18E -8.5 147.46 143.27 2600.OC 2599.41: 1.99N 15.57E 1A 2560.52 2566.6£. 53.07N 160.18E -12.0 156.82 152.47 2700.0e 2698.7e 3.53N 27.66E 1~_ 2657.47 2660.87 68.86N 176.88E -16.0 167.23 162.72 2800.0e 2797.47 5.52N 43.17E1A 2756.6E. 2757.26 84.64N 194.33E -19.8 175.29 170.61 2900.0C, 2895.62 7.93N 62.10E 1A 2856.3 2854.11 100.56N 211.45E -23.91 180.58 175.73 2943.86 2938.45 9.14N 71.47E 1A -2898.4(, 2894.96 107.52N 218.58E -25.7 182.23 177.30 3000.0C 2993.1€ 10.72N 83.88E 1A 2951.7£. 2946,72 116.14N 228.59E -27.8 184.96 179.91 3100.0C 3090.66 13.55N 105.99E 1A --_.~ 3049.81: 3041.45 129.29N 250.21 E -30.4 191.36 186.09 3200.0C 3188.15 16.37N 128.09E 1A 3150.21 3138.05 140.18N 275.12E -31.7 198.64 193.14 3300.0C, 3285.6::' 19.20N 150.20E 1A 3254.1S 3238.97 15O.23N 297.99E -33,3 202.95 197.22 3400.0~ 3383.12 22.02N 172.31 E. 1A _~_~345.7C 3327.24 158.18N _320.72E -33.9 209.02 203.03 3428.4E. 3410.8€ 22.83N 178.60E 1A 3369.5(, 3349.87 159.96N 327.86E -33.8 211.67 205.60 3500.0C, 3480.6e 24.85N 194.41E 1A 3433.0(, 3409.3£. 164.30N 349.54E -33.0 220.42 214.16 3600.0C, 3578.06 27.67N 216.52E 1A 3526.92 3495.92 169.99N 385.60E -31.0 235.78 229.28 3700.0e 3675.57 30.50N 238.63E 1A 3614.0£. 3574.76 174.78N 422.43E -28.8 254.49 247.74 'miíìiiÎjiÎírÎ~ ;~'·,',,"_,:,_,',Jf-;'.' '.' _ (i',,, ""1:::i,.,r,, :C~,:<t ,:;> -",", _, Well 'Wellbore J SurvevName ~Dfftl d Survey TOOl 1A I BC-1A . MSS<O-10296'> --_ ___- 10296.0. No Tool __- All data is in Feet unless otherwise stated Coordinates are from Slot and TVO's are from Rig (Datum #1162.0ft above mean sea level) Reference MO's are from Rig, Offset MO's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (10) Prepared by Baker Hughes Incorporated I MARATH IL C Well Beaver Creek #15 Kenai Peninsula, Alaska Prepared by: Tony Tykalsky Reviewed by: Mark Fairbanks Presented to: Will Tank . . fiFE Marathon Oil Company Well Name: Beaver Creek #15 Location: Kenai, Alaska. Marathon Oil Company PO Box 190168 Anchorage, Alaska 99519 ATTN: Will Tank Will: Enclosed is the recommended drilling fluid program for the Beaver Creek # 15 Well to be drilled this year. The following is a brief synopsis of the program. Overview: BC #15 is a development well targeting the Beluga fonnation at the Beaver Creek field. Flo-Pro fluid will be used for the intennediate and production intervals. After logging the production interval, the well will be completed with a 3-112" excape system cemented in place. Surface Interval: The surface interval will be drilled with the standard GeVGelex spud mud. No problems were noted in this interval while drilling Beaver Creek # 12 & #14. Intermediate Interval: This interval will be drilled with a Flo-Pro NT fluid. After drilling out the surface cement, the well will be displaced to a modified Flo-Pro KCl fluid with Klagard added for inhibition. SafeCarb bridging material will be maintained according to the mud program to minimize losses to the fonnation. Fluid loss should be maintained @ 7 - 9 cc's API. NOTE: Since this fluid will also be used in the production interval, care should be taken to maintain recommended mud properties while drilling the intennediate interval. Production Interval: This interval will be drilled with the same fluid that was used to drill the intennediate interval. The fluid will be pre-treated with Bicarb and/or citric acid prior to drilling out the cement. Any further fluid dilutions will be made in order to keep the mud properties at the recommended specifications. Fluid loss should be maintained @ 7 - 9 cc's API for this interval. Completion: The cement will be displaced with 6% KCl brine for the completion phase of the program. Conqor 303A and Sodium Meta Bisulfate will be added to the drilling fluid that will be left between the 3-1/2" completion string and the 9-5/8" casing on the final circulation prior to cementing. Tony Tykalsky Project Engineer 1M-I SW ACO Reference Wells: BC #12, BC #14 NOTE: This proeram is provided as a guide only. Well conditions will always dictate fluid properties required. ~IFE ~ ~FE . œ.~ ~ IFE . . Marathon Oil Company Well Name: Beaver Creek #15 Location: Kenai, Alaska. EXECUTIVE SUMMARY Our overall goal is no spills and no incidents while providing fluids and solids control services to Marathon Oil Company. Our goal for Beaver Creek # 15 is to remove drill solids from the mud system at a cost of less than $0.23 per pound. This has been the average for the last three years of centrifuge van operations With the revised fluid formulation (utilizing the intermediate interval fluid for the production interval), we expect to drill this well for a product cost of less than $23.90 per foot. Use of the MI Swaco centrifuge van for the last four years has provided an estimated savings in dilution and disposal costs to Marathon Oil of over $600,000. With continued usage of our equipment, we expect to provide more savings to you during future operations. r:zJIjlFE œm . . _FE Marathon Oil Company Well Name: Beaver Creek #15 Location: Kenai, Alaska. Interval Benchmarks and Targets Fluid cost per foot Volume Usage Solids Removal 0-2100' < $5.27 ft < 2489 bbls 2100 - < $33.46 ft < 3655 bbls 7147' 7146 - < $18.43 ft < 667 bbls 8808' Total Avg. Max. Project < $23.90 ft <6810 bbls < $0.23 Ib No Spills from Targets for Centrifuge Van Drilling Operation Interval ~IÆ~ . '~FE ~- . Marathon Oil Company Well Name: Beaver Creek #15 Location: Kenai, Alaska. Project Summary Casing Hole Casing Depth TVD Mud Mud Sum Interval Size Size Program System Weight Days Mud Cost (in) (in) (ft) (ft) Solids Control (ppg) 13 3/8" 16" 2100' 2100' GeVGelex Spud Mud 8.6 ~ 9.4 5 $14,449 Screens 150/180 mesh Desilter Centrifuge Van 9 5/8" 12~1/4" 7146' 7037' Flo~Pro w/SafeCarb 9.0- 10 $175,595 Screens 180 - 210 <9.5 mesh Desilter Centrifuge Van 3~ 1/2" 8~ 1/2" 8808' 8687' Flo-Pro w/SafeCarb ~ 7 $35,353 Screens 230 - 210 mesh Desilter Centrifuge Van 3 1/2" 8~1/2" Completion 8808' 8687' 6% KCl 8.55 2 $3,952 ~ Utilize all solids control equipment to minimize the build up of drill solids in the system (if possible, centrifuge the surface mud during trips to reduce drill solids). ~ Condition the mud prior to running casing for all intervals. ~ Due to the shallow angle of this well, no cost estimates for Lubetex usage have been made. r:zJIÎlÆ ~ . . ~IFE -- Marathon Oil Company Well Name: Beaver Creek #15 Location: Kenai, Alaska. Estimated Product Usage Summary M-I Bar 0 365 67 0 432 1.37 M-I Gel 747 0 0 0 747 2.74 Gelex 31 0 0 0 31 0.17 Soda Ash 12 18 7 0 37 0.26 Caustic Soda 12 37 7 0 56 0.69 Conqor 404 0 8 2 0 10 5.43 Sodium Meta 25 37 7 4 73 2.26 Bisulfate Bicarb 12 18 13 0 43 0.36 Conqor 303 0 0 0 4 4 0.90 FloVis 0 292 53 0 345 32.05 Desco CF 12 0 0 0 12 0.27 Polypac UL 12 146 27 0 185 13.67 Bioban BP Plus 0 37 53 0 90 0.93 KCI 0 1535 280 42 1857 11.02 Safecarb 0 1462 267 0 1729 14.27 KlaGard 0 33 0 0 33 10.82 Citric Acid 0 0 3 0 3 0.14 Defoam X 0 41 4 0 45 1.87 Engineer Service 5 10 7 2 24 ~IÆ~ . . ~IÆ Marathon Oil Company Well Name: Beaver Creek #15 Location: Kenai, Alaska. Offset Well Information Well Hole Size Depth PPG PV YP FL Comments BC #12 16 107 8.6 8 6 18 Spud in 1045 8.75 10 32 12 Drlg ahead 2100 9.4 13 17 9.6 Drlg to csg point, lower fluid loss, run 13-3/8" casing 12.25 2615 8.9 8 21 9.4 Drlg out, displace to FloPro mud drlg ahead 3941 9.1 10 22 7.6 Drlg to 3498, short trip OK, drlg ahead 5772 9.2 10 23 7.4 Drlg ahead, short tirp OK, drlg ahead 6408 9.25 12 23 6.2 Drlg ahead, trip for bit, trip OK 6848 9.25 14 20 6.8 Drlg ahead 7183 9.25 13 18 7.6 Drlg to csg point short trip, work tight spots. 2' fill. POH, rung 9-5/8" csg 8.5 7664 9.3 11 15 7.6 Orlg out, treat for cement, drlg ahead 8391 9.3 12 16 7.2 Drlg ahead. run van for clay buildup 8839 9.35 12 18 7 @ TO, centrifuge mud, run completion, displace cmt with brine Be #14 16 145 8.65 15 37 18 Spud in 1292 8.9 16 27 16 Drlg ahead, short trip OK, drlg ahead 2130 9.3 21 23 8.4 Drlg to csg point, trip OK, run 13-3/8" casing 12.25 2649 9 11 14 8.4 Orlg out, displace to FloPro mud drlg ahead 3441 9.25 11 14 8.4 Drill ahead 4534 9.15 10 19 7.6 Drlg ahead, run van for clay buildup, short trip OK 5672 9.45 10 19 8.8 Orlg ahead 6838 9.45 13 19 6.4 Orlg ahead, short tirp OK, drlg ahead 7203 9.5 12 22 6.6 Drlg to 7203' slow, POH for new bit 7610 9.8 13 22 6 Drlg to csg point, short trip, tight, backream, re-trip, OK, POH for casing 8.5 8463 9.35 12 20 6.4 Orlg out, treat for cement, drlg ahead 9238 9.3 11 20 7.2 Drlg ehad. short trip high torque, add Lubetex. drlg ahead 9361 9.5 11 20 5.4 Orlt to casing point, trip OK, Log hole 9361 9.55 13 20 5.2 Cleanout run, OK, POH run excape completion, cement same, disp to brine. r:ut;1Æ ~ . . Marathon Oil Company Well Name: Beaver Creek #15 Location: Kenai, Alaska. Plans & Procedures => COMMUNICATION - The Field Mud Engineer will communicate daily with the In-Town Project Engineer. The Project Engineer will then communicate daily with the rig Drilling Engineer. Communications should be about, but not limited to, fluid properties, hole difficulties, possible changes to the mud program, and proposals to use products not included in the mud program. => Whole Mud Losses to the Sterlng B3 and Lower Beluga Sands - Refer to fluid formulas and the Optibridge charts for maintaining proper bridging material concentration in the mud system while drilling the intermediate and production intervals. => FLUID LOSS CONTROL - In the intermediate interval the API fluid loss will be maintained in the 7 - 9 cc's range. In the production interval the API fluid will be maintained between 6 - 8 cc's at all times. In addition to sufficient fluid loss agent additions, this may require adequate dilution of the mud system in order to keep reactive drill solids to a minimum . => INTERMEDIATE INTERVAL - Note, due to the restrictive flow properties of cold, new mud, the followinq is recommended for the intermediate interval. FloVis concentration of the initial mix should be no more than 1.25 PPB. Shaker screens should be 180/180/150 until the mud warms uP. Also. whenever possible, the makeup water for the mud should be heated with steam hoses to as high a temperature as possible. Finally, the pH of the make UP water should be lowered to 5+/- 6 with Citric Acid prior to adding FloVis. After all the FloVis is added, the pH should be increased to +/- 9.5 to yield the polymer. This will reduce the tendency for the polymer to form fish-eyes. As the drilJinq fluid heats UP, FloVis concentration should be brouqht UP to 2 PPB and the end shaker screen changed to 180 mesh. => DRILL SOLIDS - MBT - The MST should be kept at less than 7.5 ppb in the intermediate and production intervals through aggressive use of solids equipment and dilution as needed. A 4 ppb Klagard concentration is recommended in the intermediate interval to minimize MST buildup and dilution requirements. => MIXING CONDITIONS - Whenever possible all treatments to the mud system should be made as pre-mix additions. Polymers and KCI should first be mixed in fresh water in that order and then blended into the active system over one or two circulations as needed. => CORROSION - Conqor 404 additions should be made daily when drilling with FloPro fluid in order to maintain a Conqor 404 concentration of +/- 2000 PPM. => CORRISION - Sodium Meta Bisulfate additions should be made daily as needed with any fluid in the hole. Maintain a DO reading of less than 3 ppm => SOLIDS VAN USAGE - The Solids Van should be used whenever drill solids become un- acceptably high and reduction of drill solids in the mud can be more economically done with centrifuging and dilution then just with dumping and diluting. The weight of the drilling fluid alone should not be the determining condition for when to use the Solids Van. => WEIGHTING UP - All increases in mud weight should be accomplished with barite additions. In the production interval, insure chloride concentration is maintained at 30,000 to minimize the need for barite additions. r:uleIÆ ~ e . ~IFE ~ Marathon Oil Company Well Name: Beaver Creek #15 Location: Kenai, Alaska. Interval Summary - 16" hole Drilling Fluid System GeVGelex Spud Mud Key Products MI Gel / Gelex / Soda Ash / Caustic Soda / MI Bar / PolyPac Supreme UL / Sodium Meta Bisulfate Solids Control Shale Shakers / Desilter / Centrifuge Van Recommended shaker screens - 150 - 180 mesh Potential Problems Lost circulation, coal sloughing, drill solids build-up, gas kick, tight hole conditions Depth Mud Funnel Yield API Drill Interval Weight Viscosity Point Fluid Loss pH Solids (ft) (ppg) (sec.lqt) (lb.llOOft1) (ml/30min) (%) 0-2100' 8.6 - 9.4 60 - 100 25 - 35 NC - 12 +/- 9.5 <7.5% ~ Treat drill water with Soda Ash to reduce hardness. ~ Build spud mud with 20 - 25 PPB M-I Gel to +/- 100 seconds/quart funnel viscosity. ~ Lower funnel viscosity to +/- 75 after gravel zone has been drilled. ~ Add Ge1ex as needed to maintain sufficient viscosity for hole cleaning. ~ Increase funnel viscosity if fill on connections begins to occur. ~ Reduce fluid loss with additions of Polypac Supreme UL prior to running surface casing. ~ Add Sodium Meta Bisulfate to maintain a DO of < 3 PPM. ~ Condition mud prior to cementing casing to reduce yield point and gel strengths. ~ Estimated volume usage for interval- 2489 barrels. ~ Estimated haul off volume - 4178 barrels. ~IFE ~ . . Marathon Oil Company Well Name: Beaver Creek #15 Location: Kenai, Alaska. Interval Summary -12-1/4" hole Drilling Fluid System Flo-Pro Fluid Key Products Flo- Vis 1 PolyPac Supreme UL 1 KC11 SafeCarb F & M 1 KlaGard MI Bar 1 Caustic Soda 1 Conqor 404 1 Sodium Meta Bisulfate Solids Control Shale Shakers 1 Desilter 1 Centrifuge Van Recommended initial shaker screens - 180/180/150 mesh Potential Problems Lost circulation, coal sloughing, drill solids build-up, gas kick, tight hole conditions Depth Mud Plastic LSRV API Interval Weight Viscosity 1 min Fluid Loss MBT Solids (ft) (ppg) (cp.) (cps) (mI/30min) (%) 2100 - 7146' 9.0- < 9.5 8 -12 30,000+ 7-9 < 7.5 +1- 5% ~ Use one rig pit to drill out surface casing. In other rig pits, build new Flo-Pro fluid using the enclosed fluid formula. Pre-heat makeup water with steam hoses as much as possible. ~ After drilling out surface casing, displace hole to Flo-Pro fluid prior to running leak offtest ~ As mud heats up, increase Flo Vis concentration to 2 PPB and install 180 mesh shaker screens on end panel. ~ Ifrunning coals become a problem, treat with a 2 PPB addition of Asphasol D. ~ If torque or sliding problems occur, add I - 3% Lubetex. ~ NOTE: This fluid will be used in the production interval. It is inherent to maintain proper fluid properties for that purpose. ~ Estimated volume usage for interval- 3655 barrels. ~ Estimated haul off volume - 4413 barrels. ~ Condition mud prior to running 9-5/8" casing. NOTE: Follow BOSCO guidelines when adding biocide, oxygen scavenger and corrosion inhibitor. r:zR;1Æ ~ Marathon Oil Company Well Name: Beaver Creek #15 Location: Kenai, Alaska. Input Beaver Creek Well #15 9,0 - 9.5 No SafeCarb 2.8 6 NOTE: Pre-heat makeup water with steam hoses as much as possible. 1 Water 298.70 0.853 298.70 2 Soda Ash 0.25 0.25 0.000 0.10 Reduce Hardness 3 Flovis 1.25 1.25 0.003 0.83 Viscosity 4 PolyPac Supreme UL 2.00 2.00 0.004 1,25 Fluid Loss Control 5 Caustic Soda 0.50 0.50 0.001 pH Control 6 KlaGard 4.00 4.00 0.008 2.67 Inhibition 7 Potassium Chloride 19.07 19.07 0.023 7.98 Inhibition 8a SafeCarb F 10.00 10.00 0.010 3.60 Brid9ing Agent 8b SafeCarb M 10.00 10.00 0.010 3.60 BridginQ A~ent If bit ballin9 becomes a problem, add the followinp: 9 D-D CWT 1.00 1.00 0.003 1.00 Reduce BHA Bal!jn~ 399 9.500 29600 1.000 350 3655 Barrels IFE Marathon Oil Company Well Name: Beaver Creek #15 Location: Kenai, Alaska. MI c:: () '§ 0.7 J:I .¡:: 1ií ë 0.6 ~ if, \\I Ü i Q.. \II 0.4 :> ¡ 1S ¡ 0.3 ::I u 0.1 400 mDarçy Max PermellÞility : Sand Control Device: © 19S9 ·2004 !vi'" I..L.C. . All Rights Ruerve<l 1.0 20 iblbbl 3.43 % 17.08 % D10 Target I Slend: 0.8 DOO Target I Ellfmd: 20.0 090 Target i Blend: 64.a 1.5 microns 16.5 microns 135,4 microns 0.9 Brand Name S=Safe·Carb 10 IF} Q;oSafe·Carb 40 1M) E-Safe·Carb 250 eC) ¡:!ridqinl.'l ÃRent¡lblbbl) !1.9 10.1 0.0 ~ 49.25 50.74 0.00 B 49.3% ~x10,2' i I , ...! ' . , ..,.., . 1)(10° 1x102 Particle Size (microns) I "'¡x'103 ' Caiclum Carbonate added: Avg Error 0 ·100 % CPS Range: Max ElTorO ·100 % CPS Range: »- Zone interest - Sterling B-3 sands » Pore Pressure - 4.4 - Maximum Porosity - 400 mD » Measured Depth - +/- 5161' (5100' TVD) » Build additional volume as needed usin~ the blend listed above. Marathon Oil Company Well Name: Beaver Creek # 15 Location: Kenai, Alaska. Flo- Vis / Polypac Supreme UL / KCl / SafeCarb F & M / MI Bar / Caustic Soda / Conqor 404 / Sodium Meta Bisulfate Shale Shakers / Desilter / Centrifuge Van Recommended shaker screens - 210 - 230 mesh Lost circulation, coal sloughing, drill solids build-up, gas kick, tight hole conditions 7146 - 8808' 9.0 - 9.5 10 -14 30,000+ 6-8 <7.5 +/- 5% » Pre-treat drilling fluid with Bicarb andlor citric acid prior to drilling cement. Aggressively treat out cement contamination as soon as feasible. additional dilution volume to maintain proper specifications. » If running coals become a problem, treat with a 2 addition of Asphasol Supreme. » Estimated additional volume for interval- 667 barrels. » Estimated haul off volume - 1864 barrels. » Condition mud prior to running 3-112" casing. NOTE: Follow BOSCO guidelines when adding biocide, oxygen scavenger and corrosion inhibitor. IFE - Marathon Oil Company Well Name: Beaver Creek #15 Location: Kenai, Alaska. Input Beaver Creek #15 9.0 - 9.5 MIBaR 4.2 No 6 1 Water 325.19 0.929 325.19 2 Soda Ash 0.25 0.25 0.000 0.10 Reduce Hardness 3 FloVis Plus 2.00 2.00 0,005 1.34 Viscosity 4 Polypac Supreme UL 2.00 2.00 0.004 1.33 Fluid Loss Control 5a SafeCarb Fine 15.00 22.50 0.017 5.67 Brid~inQ A~emt 5b SafeCarb Medium 5.00 7.50 0.006 1.89 BridQin~ A~ent 6 Potassium Chloride 20.76 20.76 0.025 8.68 Inhibition 7 CONQOR 404 2.00 2.00 0.004 1.43 Corrosion Control 8 Caustic Soda 0.50 0.50 0.001 0.23 pH Control 9 Sodium Meta Bisulfate 0.50 0.25 0.001 0.25 Oxygen Scavenger If sloughing coals become a problem add 2 . 4 ppb of the fOIIOWin, 11 Asphasol Supreme I 2,00 I 2.00 I 0.004 1.33 Well bore Stability Mix fluid in the order listed above. 360.1 380.1 667 Barrels 9.050 29600 Marathon Oil Company Well Name: Beaver Creek #15 Location: Kenai, Alaska, Corrosion Control Additive in Casing x Tubing Annulus Well Beaver Creek #15 Volumes: Tubing Volume 3·1/2" Tubing barrels Annular Volume Casing x Tubing barrels Tbg 3050 x 2.992 x 8808 ft Open Hole x Tb9 barrels Total Annular Volume Tubing Volume Total Hole Volume 558.51 76.63 635.13 x 8.681 @ 7146 ft MD -+- 8.500 x 3.50 @ 8808 fI: MD Treatment Procedures. 1. After the 3-1/2" tubing is run and the drilling fluid is circulated and conditioned for the cement job, circulate an additional 438 barrels of drilling fluid. 2. Add 1 drum of Conqor 303A and 1 sack of Sodium Meta Bisulfate for each 110 barrels of drilling fluid pumped (4 drums & 4 sacks total) 3. After the 438 barrels of drilling fluid with Conqor 303A have been pumped downhole, begin the cement job. 4. This procedure will place corrosion control in the 3-1/2" x 9-5/8" annulus. . . fiFE Marathon Oil Company Well Name: Beaver Creek #15 Location: Kenai, Alaska. HSE Issues HANDLING OF DRilLING FLUID PRODUCTS HEALTH AND SAFETY 1. Drilling crews should be instructed in the proper procedures for handling fluid products. 2. Personal Protective Equipment (PPE) charts should be posted in the pit room, the mud lab, and the office of the Drilling Forman. 3. PPE must be in good working order and be utilized as recommended by the PPE charts. 4. Product additions should be made with the intent to use complete unit amounts of products (sacks, drums, cans) as much as possible in order to minimize inventory of partial units. 5. Insure all MSDS sheets are up to date and readily available for workers to access for information. ENVIRONMENTAL 1. Insure that all product stored outside is protected from the weather. 2. Do not store partial units (sacks, etc) outside if possible. 3. Properly secure all products for shipment between job sites. 4. When transferring fluid and or cuttings from the rig to trucks, insure all hoses are properly secured. 5. When utilizing the centrifuge solids van, insure all hoses and connections between the van and the fig are secure. r:zJIìlÆ ~ Marathon Oil Company Well Name: Beaver Creek #15 Location: Kenai, Alaska. Product Function M-I BAR Weighting Agent M-I GEL Viscosity control GElEX Bentonite Extender FlOVIS Viscosifier DUAl-FlO Modified Starch POlYPAC Fluid Loss Reducer XCD Viscosifyer Circulation Material Safe-Carb F,M,C Bridging and weighting agent lO WATE Weighting agent Nut Plug Loss Circulation Material M-I Seal F, M, C Loss circulation Material Mix U F,M,C Loss circulation Material DESCO Dispersant SPERSENE CF Dispersant TANNATHIN Dispersant VENTROl 401 Surfactant SAl T (Solar) Densifier BROMIDE (NaBr) & Densifier Brine Solution POTASSIUM Shale Inhibitor CHLORIDE - - Marathon Oil Company Well Name: Beaver Creek #15 Location: Kenai, Alaska. Product Function CAUSTIC SODA Alkalinity control CAUSTIC POTASH pH Modifier BORAX Inorganic Borate SAPP Sodium Pyrophosphate SODA ASH Alkalinity control . SODIUM Alkalinity control BICARBONATE CITRIC ACID pH Adjuster BIOBAN BP-PLUS Biocide GREEN CIDE 25G _ Biocide DEFOAM X - Defoamer G-SEAL Sized graphite LCM KLA..GARD Shale Control agent LUBE Lubricant D-D CWT Detergent Con cor 404 Corrosion Inhibitor SAFEKLEEN Drilling fluid additive AsphasolD Shale Inhibitor Soltex Inhibitor Sodium Meta Oxygen Scavenger Bisulfate ~ . . Marathon Oil Company Well Name: Beaver Creek #15 Location: Kenai, Alaska. Product Health and Safety Reference HMIS HAZARD RATINGS HAZARDOUS MATERIALS IDENTIFICATION SYSTEM (HMIS) HAZARD RATINGS 4 - Severe hazard 3 - Serious hazard 2 - Moderate hazard 1 - Slight hazard o - Minimal hazard * An asterisk next to the health rating indicates that a chronic hazard is associated with the material. HMIS PERSONAL PROTECTIVE EQUIPMENT INDEX A - Safety Glasses B - Safety Glasses, Gloves C - Safety Glasses, Gloves, Synthetic Apron D - Face Shield, Gloves, Synthetic Apron E - Safety Glasses, Gloves, Dust Respirator F - Safety Glasses, Gloves, Synthetic Apron, Dust Respirator G - Safety Glasses, Gloves, Vapor Respirator H - Splash Goggles, Gloves, Synthetic Apron, Vapor Respirator I - Safety Glasses, Gloves, Dust and Vapor Respirator J - Splash Goggles, Gloves, Synthetic Apron, Dust and Vapor Respirator K - Air Line Hood or Mask, Gloves, Full Suit, Boots X - Consult your supervisor for special handling directions ~IÆ~ . . .~IFE Marathon Oil Company Well Name: Beaver Creek #15 Location: Kenai, Alaska. Contacts Contact Title e-mail Work Cellular Pete Berga Drilling pkberga@marathonoil.com 907564-6319 907 231-0663 Marathon Superintendent Will Tank Drilling Engineer wjtank@marathonoil.com 713 296-3273 713 203-8398 Marathon Tony Tykalsky Project Engineer ttykalsky@miswaco.com 907274-5011 907 227-2412 MISWACO Gus Wik Warehouse Manager gwik@miswaco.com 907776-8722 907776-8680 MISWACO Michael Barry Senior Field gratefulmen@hotmail.com 907 260-4666 907 590-3636 MISWACO Engineer (home) Locke Rooney Field Engineer rooneyl@alaska.net 907 235-0598 907 590-3636 MISWACO (home) Roland Lawson I Drilling Foremen 907283-1312 Larry Myers I Dave Morris Marathon Responsibilities þ>- MI Project Engineer and will coordinate daily between the Marathon office, rig, warehouse, and the M-I field engineers. þ>- Well progress will be monitored to look for any changes, which will improve the efficiency of the operation or avert trouble. þ>- Field Engineers will monitor and supervise product inventory to include re-palletizing any products for shipment to other locations at the end of the well. þ>- Field Engineers will communicate with office personnel (Marathon & MI SW ACO) for approval of any changes in the mud program (including introduction of new products). þ>- Field Engineers will produce a recap at the end of the well based on daily activities. Recap should include any lessons learned that may be used to provide better service on future wells. Lessons learned can include changes in procedures, product additions, equipment usage, and/or utilization of any third party service. r:zJItlÆ ~ Check No Check Date Bank Bank No .'No Marathon Oil compan. p, 0, Box 3128 Houston, TX 77253 ~æ¿~~¥~~A~~BlE DEPARTMENT Aeels Payable Contact Center Phone: 918-925-6097 ··············\;«j~ii#Wii##/V·Þ!i#.®.t: "" 100.00 100.00 Hndlg HS 1140B29 09/03/2004 NCBAS :jWiIii~~Wí~~tih.Wi6~6Mi A0100.00 " "09/()3t2004 77BO 5001123 ..ii:AAi¥iiiiiŒiii )) 19OO0253BB TOTAL: )ffliM¢ÞiiiiMiiH< ·¡;m¡¡¡~~~~tV," , 100.ó6 100.00 (FOLD ON PERFORATION BELOW AND DETACH CHECK STUB BEFORE DEPOSITING) 'II'~[I ~ I tJ,,~..,.., J ~III :I-"}."' "~';m l~rtJ :'~UI', ~,~ l'...: I =-~: 1:( tJ;iI :J~t ~ ~{~:{ 11' J ~I' ~';J.:lI~"Jrl) ~..=-..: I :l1I1~:tI:J =I. .')'¡'''I{'Jö.'~j ~t=J)'~r'' ;~'J~iÜ~UI~r" IIlnnn ¡, ¡, LnR i][~1I1 .:0 L ¡, 20 :IS ~ 5.: 0 ¡,a j I.a 1.111 . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER I; WELL NAME ~é /~ PTD# 2o~-/g7 X Development Service CHECK WßA T APPLIES ADD-ONS (OPTIONS) M1JLTJ LATERAL (U APJ num ber last two, (2) digits are between 60-69) Exploration Stratigraphic "CLUE". The permit is for a new weJlbore segment of existing well, , Permit No, ,'API No. Production. should condnue to be reponed as a function 'of the original API number, stated above. BOLE In accordance with 20 AAC 25.005(f), an records, data and logs acquired for tbe pilot bole must be dearly differentiated In both name (Dame on permit plus PH) and API Dum ber (SO 70/80) from records, data and logs acquired for we)) (name on permit). PILOT (PH) SPACING EXCEPTJON 6'e<::. ~ ;fe.vf7 ~~ x DRY DITCH SAMPLE The permit is approved subject ·to fuO compUaDce with 20 AAC 25.0SS~ Approval to perforate aDd produce is contiDgeDt UpOD issuance of ~ conservation order approving a spacing eneption. {Company Name} assumes tbe liability of any protest to tbe spacing ,exceptioD tbat may occur. AU dry ditch sample sets submitted to tbe CommissioD must be i)) ))0 greater 'tbaD 30' sample inten-als from below tbe permafrost or from wbere samples are first caugbt and ] 0' sample inter:vals tbrough target zones. llIO hULll,~ - u'~aVI';i creek No. l~acing Exception ~J ~ . http://www.state.ak.us/local/akpages/ADMIN/ogclhear/BCU_15.htm . Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: The applìcation of Marathon Oil Company ("MOC") for a spacing exception to allow the drilling and operation of the proposed Beaver Creek Unit No. 15 ("BCU 15") gas development well in accordance with Conservation Order No. 237. MOC by letter dated August 31,2004 and received by the Alaska Oil and Gas Conservation Commission ("Commission") on September 3, 2004, has requested the Commission issue an order in conformance with 20 MC 25.055 allowing drilling and operation of the proposed BCU 15 gas development well. The surface location of this well will be 91 feet from the south line and 1,443 feet from the east !ine of Section 33, T07N, R10W, Seward Meridian ("SM"). The proposed bottom hole location wi!! be 200 feet from the south line and 250 feet from the east line of Section 33, T07N, R10W, SM. Rule 3 of Conservation Order No. 237 ("CO 237") governs well spacing for gas pools within the Beaver Creek Unit An exception to Rule 3 of CO 237 is required as BCU 15, if productive, wíl! be the second gas development well open to the pool in the SE/4 of Section 33, T07N, R10W, SM, and it may also be open to regular production within 1,320 feet of an existing well that is completed in the same pool. The Commission has tentatively set a public hearing on this application for October 26, 2004 at 9:00 am at the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, A!aska 99501. A person may request that the tentatively scheduled hearing be held by filing a written request with the Commission no later than 4:30 pm on September 30,2004. If a request for a hearing is not timely filed, the Commission may consider the issuance of an order without a hearing. To learn if the Commission will hold the public hearing, please call 793-1221. !n addition, a person may submit written comments regarding this application to the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. Written comments must be received no later than 4;30 pm on October 15, 2004 except that if the Commission decides to hold a public hearing, written protest or comments must be received no later than the conclusion of the October 26, 2004 hearing, If you are a person with a disability who may need special accommodations in order to comment or to attend the public hearing, please contact Jody Colombie at 793-1221. John K. Norman, Chair Published Date: September 13, 2004 AO # 02514015 --~,_"-«_,_,_"'_,_,,«_,_,>:<_,_,->:-,,___,___,_,_,;-»:_,_,__,_=,'»"/~_h- -,,,,,,_,,____,_,_;.',->,,_,*,,,*,_,_,_,,..ú;_»:·c;_;·»ô_;,,*,_;_;_';«-'_ Calendar Home Webmaster 1 of 1 9/2312004 I :45 PM Field & Pool BEAVER CREEK, BELUGA GAS - 80500 Well Name: -BEAVER CK UNIT 15 Program DEV Well bore seg 0 PTD#: 2041870 Company MARATHON OILCO Initial ClassfType DEV 11-GAS GeoArea Unit On/Off Shore .On Annular Disposal 0 Administration 1 p~(lnit fee attached. - - - - - Y~$ 2 .Leas~number .appropriate. . . - - - - · Y~s 3 .U,nique weILn,arn~.a[1d Ol!mb.er . . . . . . . . . . . . . . . . . . . . . . . . ... .. .Y~s - - - - - - . - - - - - - - - - - - - - - -- _. . - - - - - - - - - - - - - - - . - - - - -- 4 WeJlJocat~d in.a d.efined .pool. . . - - - - - Y~s - - - - - 5 WeJlJocated proper .distance from drilling unitbound.alY. - - - - - No COl1servatioo Ord.er 23.7, wle3.e.stablishes. BeJu.ga G.as Pool spa.cing at 40ac.. This. well wilLhave a 20ac sp. 6 WellJocat~d proper .distance. from other wells. . . . No MOC .has aPplied. for.a. spacing exception whic.h.h.as been .notic~d.Approval perforate andpro.duce. tbis wel 7 S.uff¡cient .acreage .ayail.able in dJilIiOg ¡¡njt. ...... No. is con.ti[1gent on MOC re.œiyiog the spa.cing eJ¡~ptlon.. R¡:>C 8 Jf.deviated, js. weJlbore platincJu.ded . - - - - - - - - - - ...... Y~s 9 .Operator onl~ affected party. . ...... Y~s - - - - - - 10 .Operator bas.appropriate.Qol1d lnJorce . . . . . . . . . . . . . . . . .. _..... Y~s .. . - - - - - - - - - - - - - - - - - - - - 11 P~rmit cao be lSSl!ed without co.nservatiOI1 order. . . - - - - - No - - - - . Appr Date 12 p~(I1']it can be lssl!ed witbout ad.ministratille.approvaJ . - - - - Y~s - - - - RPC 9/23/2004 13 Can permit be approved before 15-day wait Yes 14 WeJlJocated within area an.d.strata .authorized by. Injection Ord~( # (puUOtl in.COO1rn~nts)(For. .NA - - - - - - 15 All wells. within .1 l4.l1Jite.area.of reyiew id~nt!fied (For servj~.well onl~L . . . . . _ . . . . . . . . .NA .. . - - - - - - - - - - - - - - - -- 16 Pre.-produceq injector; duration.of pre-production Less than. 3. mOl1ths (Forseevlce well only) . NA - - - - -- 17 ACMP.Fjl1ding .of Con$i$tencyh.as bee.nissued. for. tbis proiect. . ...... .NA Engineering 18 .Conductor string. provided . . . - - -- · Ye$ 2Q" @ 144'.. . . . - - - - - - 19 .S.ui:fac~ .casingpJotec.ts alLknown USDWs . . . . . . . . . . . . . Y~$ 20 CMT v.ol adeQl!ate. to circ.ulate. on conductor & $u.rf C$g . Y~s Adequate excess, . . '21 CMT vol adeQl!ate. to tie-in .long .string to surf csg. . Y~$ - - - - - - 22 .CMT-will coyer all know.npro.ductiye bori~on.s. . . Yes - - - - - - 23 .Ca$ing de.signs adequate for C,T., ß80 RermafrO$t. . .Y~s 24 Adequ<ltetan.kage.oJ re.serye pit. Y~s Glacier Rig 1. 25 Jfare-d(iII" has.a 10:403 for .abandon.ment be~n apPJoved . . . . NA l\Iewwell, ì 26 Adequ.ate.wellbore separatjo.nproposed. . . . . . . . . . . . . . . . . . . . . . . . . . . , . .Y~s .. . - - - - - - - - - - - - - - - - - - - - 27 Jfdivecter req.uired. does it meet reguJations. . . . .Y.e$ - - - - - - . Appr Date 28 .Drilling fluid program $chematic& eC .uip li$tadequate. . . - - - - Y~$ Max MW9,5 RP9·. . . WGA 9/24/2004 29 B.OPEs,.do .they meet reguJatiol1 . - - - -- Y~$ 30 .BOPEpress ra.ìiog appropriate; Jest to.(puJ psig tncom01eot$) . .Y~$ T estt.o 2500 psi. . MS¡:> 1945 P$i.. 31 .C.hoke.l1Janifold compJies w/API R~-53. (May 64) Y~s 32 Work will occ.U( withoutoperatio.nsnutdow.n. - - - - - - Ye$ 33 Is presence. of H2S gas. probable. - - - - - No. 34 MeçhanicaLconditlon of wells withil1 J1.0R yerifiecl (for.s.ervjce well only). NA - Geology 35 Permit c.an be iSSl!ed wlo. hydrogen sulfide meé!SjJ(es. . - - - -- Ye$ 36 .D.ata.preseotecl on. Rote.ntié!1 oveJpres.sur~zones. - - - - - NA Appr Date 37 .S~is01icanalysjs. of sbaJlow gé!szooes. NA RPC 9/23/2004 38 .S~abedcondjtioo survey (if off-shore) . . · .NA - - - - /39 Conta.ct namelp)1onefor.we~lsly progress.repo.rts [exploratolY .only). . . .. .NA Geologic Date: Engineering Date ~ Date Commissioner: Commissioner: C sioner 1/2f Î<J.. ,%17dJ£
