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Home My WebLink About205-069 · . 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. «.0 S - Db,! Well History File Identifier Organizing (done) D Two-sided 11I1111111111111111 RES CAN ~color Items: ,~reYSCale Items: D Poor Quality Originals: DIGITAL DATA D Diskettes, No. D Other, NolType: D Other: NOTES: Oato cgJ3DJD7 oatoß' lað/ D7 3 0 + BY: C Mari~ Project Proofing BY: C- Mari0 Scanning Preparation BY: Date: Production Scanning m£ 1111111111111111111 /5/ ntP II = TOTAL PAGES 10J (Count does not include cover sheet) /5/ o Rescan Needed 1111111111111111111 OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: D Other:: /5/ 1/1111111111111111I Stage 1 Page Count from Scanned File: J 0 d- (Count does include cover sheet) VYES Page Count Matches Number in Scanning prelaration: 0:) oato'3/3O/07 Stage 1 If NO in stage 1, page(s) discrepancies were found: BY: BY: Maria Date: Scanning is complete at this point unless rescanning is required. YES NO /51 mp NO ReScanned BY: Maria Date: Comments about this file: 151 1111111111111111111 11111111111I11 1111I /5/ Quality Checked 1111111111111111111 101612005 Well History File Cover Page.doc .. . . ÍÂ\ w w FRANK H. MURKOWSKI, GOVERNOR AI{ASIiA OILAlWD GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Tim Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196247 Anchorage, Alaska 99519 Re: McArthur River M-17 Union Oil Company of California Permit No: 205-069 Surface Location: 1053' FNL, 454' FWL, SEC. 33, T9N, R13W, SM Bottomhole Location: 2270' FSL, 89' FEL, SEC. 32, T9N, RI3W, SM Dear Mr. Brandenburg: Enclosed is the approved application for permit to drill the above referenced development well. A spacing exception is not required to drill and operate this proposed well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. 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. PIe rovide at least twenty-four (24) hours notice for a representative of the Commission t itne s any required test. Contact the Commission's petroleum field inspector at (907) 659- 507 (p er). ~~al1 '-- DATED thisiL day of May, 2005 cc: Department of Fish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. Re: M-17 Permit to Drill Questions . . Subject: Re: M-17 Permit to Drill Questions From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Mon, 09 May 2005 12:25:43 -0800 To: "Magee, Neil" <mageen@unocal.com> Neil, Thanks, my questions are answered. Tom Magee, Neil wrote: Hi Tom, I. We're working with Reeves (Precision Drlg) to provide some of the logging for this well due to the number of depleted zones we'll be encountering. (Our mud at 9.2 ppg will be 1400-1600 psi overbalance in the 8-1/2" and 6-1/8" hole sections.) As we require pressure sampling and open hole logs in both sections we are looking at using the through DP option that Precision has for the MFT (Precision's Formation Pressure Sampling tool) rather than Schlumberger's MDT conveyed on drill pipe because we believe there is a moderate chance of sticking this expensive tool. Schlumberger is still working to offer us an alternative to the DP conveyed MDT but in the meantime we're specifying "Precision" in the program. APRS will be provided the wireline unit to convey the tools in the hole as Precision does not have an offshore skid in the Inlet yet. In the 6-1/8" hole section we currently plan on using Schlumberger for the Quad combo and Precision/ APRS to run the MFT logs. 2. The plan is to bring the 7" cement back 200' inside the 9-5/8" shoe - not to surface as indicated in Step 11. 3. The close approach analysis indicates that M-13, 14 and 15 are all of concern. For that reason we've elected to run gyro surveys during the kick off to at least 1200' to ensure we maintain separation. Our plan is to monitor these three wells during this period and if the separation becomes less than designed in our close approach analysis, we'll set a downhole plug and bled off the casing and tubing pressures from the well in question. I'll add verbiage in the "Hazards and Contingencies" section to reflect that. 4. The stack will have blind rams in the middle cavity. So for the 5" scenario well have (from bottom to top) 5" pipe rams, blind rams, 5" pipe rams, When drilling the 6-1/8" hole section we'll have 3-1/2" drill pipe to surface. So from bottom to top we'll have 3-1/2" pipe rams, blind rams" 3-1/2" pipe rams. I'll add that detail to the "Well Control Specifics". I've attached the program with the changes discussed above. 10f4 5/9/2005 12:28 PM Re: M-17 Permit to Drill Questions . . Regards, Nei I Magee 263-7804 From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, May 09,20058:37 AM To: Magee, Neil Subject: Re: M-17 7" Cement Slurries Neil, Thanks for the note regarding the slurry change. I will note the change in the permit application. I have been looking at the application and had a couple of questions. 1. In your step-by-step procedure on page 8, in step 10 it is noted to RU APRS for logging. Is this a new service for APRS?? Later you note to RU SOS for deeper logs. 2. In step 11 you note to cement the 7" back to surface, but elsewhere it is noted to only cement up into the 9-5/8" casing. Based on your most recent message, it would appear the you only intend to bring the TOC to ~200 feet above the 9-5/8" shoe. 3. Based on your close approach discussion on page 9, is there any plan to SI any ofthe identified wells?? You do note about having an operator posted in the well room to monitor/listen for any indication of collision. 4. On your stack drawing, no blind rams are shown. 5. Also, could you provide a listing of how the rams will be configured during the various stages of the well. Reading through your hazards and contingencies section I note that you will be using both 5" and 3-112" DP. Thanks in advance for your reply, call or message with any questions. Tom Maunder, PE AOGCC Magee, Neil wrote: Tom, We have adjusted the 7" casing cementing job by utilizing 12.5 ppg LiteCrete instead of 15.8 ppg G as the tail cement in Steel head M-17. I've attached the revised cement program. Can you make this notation in the approved permit to drill. Thanks, Neil Cement Calculations: 20f4 5/9/2005 12:28 PM Re: M-17 Permit to Drill Questions . . Casing Size 113-3/8" Surface I Basis: Lead: Based on 410' of 28" conductor, 114' of open hole volume @ 200% excess. Lead TOC: To surface at 78' RKB Tail: Based on 250' open hole volume @ 50% excess + 80' shoe track volume. Tail TOC: At -602' MD rotal Cement Volume: Lead 261 bbl/1464ft3 1440 sks of Dowell CemNET "G" blend at 11.0 ppg and 3.33 cf/sk. Tail 41 bbll 230 fë I 200 sks of Dowell CemNET "G" blend at 15.8 ppg and 1.17 cf/sk. Casing Size 19-5/8" Intermediate Longstring I Basis: Lead: Based on 410' of 27" x 9-5/8" conductor annulus, 291' of 9-5/8" x 12-1/4" annulus @150% excess Lead TOC: To surface at 78' RKB Tail: Based on 250' MD open hole volume + 50% excess + 80' shoe track volume. Tail TOC: At -1141' MD rotal Cement Volume: Lead 85 bbl/476t3/183sks of Dowell CemNET 'G' blend at 12.0 ppg and 2.60 cf/sk. Tail 26.8 bbl/151 fë 1128 sks of Dowell CemNET 'G' blend with GASBLOK at 15.8 ppg and 1.17 cf/sk. Casing Size 1 7" Production Longstring 1 Basis: Lead: Based on TOC 200' above 9-5/8" casing shoe at 1391' MD. 50% excess in open hole from 3360' to 1513' MD Tail: Based on cement from TO at 5497 (4750' TVD) to 3360'MD (To cover A2 sand at 2700' TVD) + 50% excess + 80' shoe track volume. Total Cement Volume: Lead 71.5 bbl/401 ft3 ¡ 192 sks of Dowell G blend at 12.5 ppg and 2.09 cf/sk. Tail 75.2 bbl/421 ft3 1188 sks of Dowell LiteCrete 'G' at 12.5 ppg and 2.24 cf/sk. Casing Size 13-1/2" Production Liner I Basis: Lead: Based on cement from TD at 6779' to the liner top at 5247' MD plus 3-1/2" DP x 7" casing annulus to 5100' MD. Open hole volume from 7" shoe to TO at 50% excess + 40' shoe track volume. Total Cement Volume: 55 bbll 308 ft3 I 265 sks of Dowell Premium 'G' at 15.8 ppg and 1.16 cf/sk 30f4 5/9/2005 12:28 PM Re: M -17 Permit to Drill Questions 40f4 . . 5/9/2005 12:28 PM · Unocal Corporation . P.O. Box 196247 Anchorage. AK 99501 Telephone (907) 263-7660 UNOCAL. RECEIVED APR 2 9 Z005 Alaska Oil & Gas Cons. Commission Anchorage Tim Brandenburg Drilling Manager April 22, 2005 Alaska Oil and Gas Conservation Commission 333 West ih Avenue Anchorage, Alaska 99501 Attn: Commissioner Seamount Re: Application for Permit to Drill (Form 10-401) McArthur River Field Steel head Platform, Well M-17 Commissioner Seamount: Enclosed for your review and approval is the Application for Permit to Drill the Steelhead Well #M-17. This well will be drilled from an existing empty well slot and is designed to be a directionally drilled Grayling Gas Sand producer with a proposed TD of 6032' TVD RKB. We are planning to drill a 17-1/2" hole to 850' utilizing a 21-1/4" diverter and then run 13- 5/8" casing. We will then nipple-up the 16-5/8" 10M BOP and directionally drill 12-1/4" hole to the 9-5/8" casing point at 1350' (as mandated in Administrative Approval No. 228.1 Rule 4). Next, we will drill 8-1/2" hole to 9-5/8" casing point at 4750' and then drill 6-1/8" hole to the programed TD. The well will be completed utilizing a 3-1/2" liner and 3-1/2"completion string. We are planning to utilize a water base drill fluid, with the cuttings disposal occuring as per Steel head NPDES Permit # AKG285019. The expected date for work to begin is approximately June 1, 2005. If there are any questions, please contact Neil Magee at 263-7804. Sincerely, --z Tim Brandenburg Drilling Manager Unocal Alaska ORIGI[~AL _ STATE OF ALASKA _ ALAWA OIL AND GAS CONSERVATION COM~ION PERMIT TO DRILL 20 AAC 25.005 RECF'\;t-. } 1 b. Current Well Class: Exploratory D Development Oil D Multiple Zone 0 Stratigraphic Test D Service D DeveloprrAl?8as2l9J 2$JW)e Zone D 5. Bond:. Blanket.~ Single Wel!D . i1~e:1 Name and N~m~er:. Bond No.'s-5"3i..fZ78' ~Al!J-ãska 011 ~~~IIAC''OmmISSIOn 6. Proposed Depth: ~ 1AmJh'I'!gfJ(s): MD: 6779' / TVD: 6038' / Mcarthur River Field 7. Property Designation: j}1> ,_ Grayling Gas Sands ADL-18730.4-.PL /1>'f« ç.'f'''?~ , 1a. Type of Work: Drill 0 Redrill D Re-entry D 2. Operator Name: Union Oil Company of Califomia 3. Address: PO Box 196247, Anchorage. AK 99519 4a. Location of Well (Govemmental Section): Surface: 1053' FNL, 454' FWL, Sect 33, T9N, R13W, SM Top of Productive Horizon: 2270' FSL, 89' FEL, Sect 32, T9N, R13W, SM Total Depth: 2270' FSL, 89' FEL, Sect 32, T9N, R13W, SM 4b. Location of Well (State Base Plane Coordinates): Surface:x- 214070.15" y- 2499450.46 ~ Zone- 16. Deviated wells: Kickoff depth: Maximum Hole Angle: GGS 500 feet 53 degrees 18. Casing Program: Size Casing 28" Specifications Weight Grade 133 X-56 68 L-80 40 L-80 26 L-80 9.2 L-80 Coupling Weld Butt Butt Butt-m IBT-m Length 480' 852' 1513' 5491' 6779' Hole exist 17-1/2" 13-3/8" 12-1/4" 9·5/8" 8-1/2" 7" 6-1/8" 3-1/2" As'y 8. Land Use Permit: 13. Approximate Spud Date: 6/1/2005 9. Acres in Property: 14. Distance to Nearest Lease 3840 acres Property: 10090' to Unit B. Line 10. KB Elevation 15. Distance to Nearest Well (Height above MSL): 160 feet Within Pool: 93' from B5 in M-15 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2640 psi Surface: 2421 psi ,- Setting Depth Quantity of Cement c.f. or sacks Top Bottom MD TVD MD TVD (including stage data) 0 0 480 480 Driven 0 0 852 850 1464 cuft Lead, 230 cuft Tail . 0 0 1391 1350476 cuft lead, 151cuft Tail . 0 0 5497 ' 4750 409 cuft Lead, 422 cuft Tail 5247 4558 6779 6032 265 cU.ft. 15.8 ppg G Blend 19. Total Depth MD (ft): PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Structural Conductor Surface Intermediate Production Liner Size Length Perforation Depth MD (ft): Cement Volume MD TVD Filing Fee ~ BOP Sketch ~ Property Plat 0 Diverter Sketch 0 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Perforation Depth TVD (ft): Time v. Depth Plot U Drilling Fluid Program 0 Date Contact Shallow Hazard Analysis U 20 AAC 25.050 requirements 0 Timothy C. Brandenburg ,--Þ, ?-p~o)~· ~ /~" ,// Permit to Drill, . 9 API Number: <-- Number: 2ô5"-()0 ,,50- 733- 2D..5SI- 66 Conditions of approval: ~ Sample requir d Yes D No ~ Mud log required .~ D No gT4' . C Hydr. en s de measures Yes D No ¡;g¡ Directional survey required, ß Yes ~ No ~ Other:"'" ,\. - I"'ÍÍÎÃ('o.,.\.~L~:rY"o...~<:.\.o,-\-C~\~~::S",>V~-")~\~C::1; ~\~\\'\~\ ~~-\~"»,.... I 7l,zr,,'~ APPROVED BY ~/ / _ ~ Approved b~ j /' A THE COMMISSION Date: c~ /il / ~ V ~ - ~ ('Ì. I ,.f\' ! I Form 10-401 Revi d 06/ 04 ¡ L Submit inDuplicate ;'.1 r\ 20. Attachments: Printed Name Signature Drilling Program J Seabed Report D Title Drilling Manager Phone 907-276-7600 Date L/_ Zg>-OS- Commission Use Only Permit Approval Date: See cover letter for other requirements. . . ¡Well Name: IM-17 RECEIVED APR 2 9 2005 Al8~ka Oil 84 Gas dons. Commission Anchorage Drill and Complete Plan Summary 1 Type of Well (service I producer I injector): 1 Producer x = 214,070.15' Y = 2,499,450.46' 1053'FNL,454'FVVL, Sec. 33, T9N, R13E X = 213,483.1' Y = 2,497,505.97' 2270'FSL, 89'FEL,Sec. 32, T9N, R13E X = 213,483.1' Y = 2,497,505.97' 2270'FSL,89'FEL,Sec.32,T9N,R13E I AFE Number: 1163917 1 Estimated Start Date: 15/25/2005 1 Rig: I Steel head I Operating days to complete: 129.0 1 I I I [}Æ[] 6779' 1 TVD: 16032' I I RKB/BF: 178' 1 RKB/MSL: 1160' I Objective: I Grayling Gas Sands The wellbore approached within 93' of the 85 sand currently being produced in M-15 The well approaches within 10,090' of the nearest unit boundary line. c IT b- p aSln gl U Ing rogram: Hole Csgl WtlFt Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MDITVD bkb 28" 91.5# H-40 WLD 410' BF 488/488 17-1/2" 13-3/8" 68# L-80 BTC 772' BF 850'/847' 12-1/4 9-5/8" 40# L-80 BTC 1313' BF 1391 '/1350' 8-1/2" 7" 26# L-80 BTC-m 5419' BF 5497'/4750' 6-1/8" 3-1/2" 9.2# L-80 I BT -mod 1532' 5247'/4499' 6779'/6032' Tubinq 3-1/2" 9.2# L-80 IBT-Mod 5169' BF 5247' 13-3/8" burst 5020, collapse 2270 psi 9-5/8" burst 5750 psi, collapse 3090 psi 7" burst 7240 psi, collapse 5410 psi 3-1/2" burst 10160 psi, collapse 10530 psi M-17 Drilling Program - AOGCC (') \,." L Page 1 . . Directional: Ver. BHI Ver #4 Slot 9 SWL KOP: 500' Maximum Hole An Ie: Close Approach Wells: RECEf\/ED APR 2 9 2005 53 degree~ at 2046' MD All Wells Pass Major Risk Criteria M-13 - 22' or less to 800' (Ellipse separation 19') M-14 - 23' or less to 750' (Ellipse separation 19') M-15 - 21' or less to 900' (Ellipse separation 17') 1011 Survey Program: Standard MWD surveys Gyro survey required in surface hole.to approximately 1200' 17-1/2" Surface Hole Fresh Water Surface Hole Mud PH 8.5-9.0 ./'* 12-1/4" Intermediate 850' -1391' : Fresh Water Surface Hole Mud PH 8.5-9.0 ./' 8-1/2" Intermediate 1391-5419: KCL Pol mer PH 8.5 -9.5 KCL Pol mer PH 8.5 -9.5 6-1/8" Production Hole 5419-6779' : Testin . Depth Test Type 20' below casing shoe 20' below casing shoe 20' below casing shoe LOT LOT LOT Minimum EMW Basis 25bbl kick tolerance 10.7 EMW 10.8 EMW 10.7 EMW ~ M-17 Drilling Program - AOGCC Page 2 . . Lo in Surface 12-1/4" Hole Section 8-1/2" Hole Section RECEI\/ED APR 2 9 2005 A1aska Oil & Gas Cons. Commissíon Anchora e 6-1/8" Hole Section Drillin : Drillin : Drilling: o en Hole: Drilling: Open Hole: Sampling Cased Hole: None Planned MWD I GR I RES MWD I GR I RES MWD I GR I RES GR/RES/DEN/NEU, Pressure Sam lin MWD I GR IRES GR/RES/DEN/NEU/SON, Pressure / .I Formation Markers: Tan:~et Top TVD/SS Depths Pore Pressure (PSI) EMW Requirement (RKB) SZll -1344 657 8.4 ppg SZ12 -1468 300 3.6 ppg SZ17 -1912 615 5.7 ppg SZ22 -2310 615 3.1 ppg A2 -2551 490 3.5 ppg A3 -2678 490 3.3 ppg AS -2764 490 3.2 ppg A6 -2925 285 1.8 ppg B2 -3111 285 1.7 ppg B3 -3203 285 1.7 ppg B4 -3273 425-1500 2.4ppg - 8.6 ppg B5 -3430 425 2.3 ppg B6 -3482 425 2.3 ppg C1 -3763 375 1.9 ppg C3 -3878 490 2.4 ppg C5 -3991 1810 8.5 ppg Dl -4140 840 3.8 ppg D2 -4445 600 2.5 ppg D3B -4606 650 2.6 ppg D6 -4877 900+ 3.4 ppg+ D14 -5725 2640 8.6 ppg TD -5878 / / M-17 Drilling Program - AOGCC L Page 3 . . Cement Calculations: Casin Size 13-3/8" Surface Basis: Lead: Based on 410' of 28" conductor, 114' of open hole volume @ 200% excess. Lead TOC: To surface at 78' RKB Tail: Based on 250' open hole volume @ 50% excess + 80' shoe track volume. Tail TOC: At -602' MD Total Cement Volume: Lead 261 bbl I 1464ft 1440 sks of Dowell CemNET "G" blend at 11.0 and 3.33 cf/sk. 41 bbl I 230 ft 1200 sks of Dowell CemNET "G" blend at 15.8 and 1.17 cf/sk. Tail Casin 9-5/8" Intermediate Longstring Basis: Lead: Based on 410' of 27" x 9-5/8" conductor annulus, 291' of 9-5/8" x 12-1/4" annulus @150% excess Lead TOC: To surface at 78' RKB Tail: Based on 250' MD open hole volume + 50% excess + 80' shoe track volume. Tail TOC: At -1141' MD Total Cement Volume: Lead 85 bbl 1476t I 183sks of Dowell CemNET 'G' blend at 12.0 and 2.60 cf/sk. 26.8 bbl 1151 ft 1128 sks of Dowell CemNET 'G' blend with GASBLOK at 15.8 and 1.17 cf/sk. Tail Casin Size 7" Production Longstring Basis: Lead: Based on TOC 200' above 9-5/8" casing shoe at 1391' MD. 50% excess in open hole from 3360' to 1513' MD Tail: Based on cement from TD at 5497 (4750' TVD) to 3360'MD (To cover A2 sand at 2700' TVD + 50% excess + 80' shoe track volume. Total Cement Volume: Lead 71.5 bbl 1401 ft 1192 sks of Dowell G blend at 12.5 ppg and 2.09 cf/sk. Tail 75.2 bbl 1421 ft I 188 sks of Dowell LiteCrete 'G' blend at 12.5 and 2.24 cf/sk. Casing Size 3-1/2" Production Liner I Basis: Lead: Based on cement from TD at 6779' to the liner top at 5247' MD plus 3-1/2" DP x 7" casing annulus to 5100' MD. Open hole volume from 7" shoe to TD at 50% excess + 40' shoe track volume. Total Cement Volume: 155 bbl I 308 ft;j I 265 sks of Dowell Premium 'G' at 15.8 ppg and 1.16 cf/sk M-17 Drilling Program - AOGCC Page 4 . . Well Control: Surface hole will be drilled with diverter. The diverter system consists of a 21-1/4" x 500 psi annular preventer, a 30" x 500 psi riser and two 16" diverter lines with hydraulically actuated ball valves. The intermediate and production hole well control equipment will consist of 10,000 psi working pressure blowout preventer stack outfitted with pipe rams(2), blind rams, and annular preventer. Based upon the maximum anticipated surface pressure the BOP equipment will be tested to 3000 psi. BOP equipment will be tested on a 14 day basis. BOPE Stack Arrangement with 5" DP in use - Top to bottom Annular 5" Pipe Rams Blind Rams 5" Pipe Rams BOPE Stack Arrangement with 3-1/2" DP in use - Top to bottom Annular 3-1/2" Pipe Rams Blind Rams 3-1/2" Pipe Rams Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- · Maximum anticipated BHP: · Maximum surface pressure: 8.6 ppg EMW, 2640 psi @ 5725'TVDss +160' RKB 2421 psi @ surface (based on 2640 psi at D14 and a full column of gas @ 0.10 psilft) · Planned BOP test pressure: · Planned completion fluid: 3000 psi 8.6 ppg filtered seawater with 3% KCL Disposal: · Cuttings Handling: Cuttings generated from drilling operations will be discharged overboard as per NPDES Permit · Fluid Handling: Drilling and completion fluids will be discharged overboard as applicable under NPDES Permit H2S: · Gas produced from the Grayling gas sands have contained no significant levels of H2S. The Steel head facility however requires that all safety equipment and procedures for dealing with H2S gas be in effect. M-17 Drilling Program - AOGCC Page 5 . . §pecial Precautions to Ensure Well Control on Steelhead Platform In December 1987 the Steel head M-26 blew out which resulted in a fire and explosion which caused extensive damage to the platform. The primary reason for the blowout was due to the unloading of a shallow gas sand at 2040' as a result of an underbalance wellbore created during the pumping of a 200 bbl unweighted water spacer prior to cementing the 13-3/8" casing. The reduction in hydrostatic pressure resulted in an underbalance of approximately 20 psi over the highly permeable AD-2 and AD-4 gas sands. The well was placed on the diverter once the influx was noted, however it was estimated that the well was unloading in a rate in excess of 100MMCFD and the surface diverting equipment soon failed. The post well review by a Marathon investigative party determined that cause of the blowout was as follows: "The primary cause of the blowout on well M-26 was a casing program that did not allow the well to be restricted or shut off during a kick, and relied on a diverter system for well control. A diverter is not a well control system, it is only a method to allow gas kicks to be temporarily released overboard, allowing personnel to be safely evacuated. If sufficient casing had been installed before drilling the shallow gas sands, it is unlikely that, even with the noted kick, a blowout would have occurred on well M-26". The well programs since that time have incorporated an additional casing string such that a BOP stack is in place prior to drilling these prolific gas sands which commence at approximately 1500'. In addition extensive modifications have been made to the surface diverter system to handle large discharge volumes. Still additional precautions must be taken to ensure that the drilling of the shallow gas sands in M-17 can be done in a safe manner. 1. Cement spacers and washes must be maintained at densities that will prevent well kicks. 2. Mud properties will minimIZe swab and surge pressures. Trip speed will be monitored to minimize the effects of these pressures. 3. The fluid level in the well bore should not be allowed to drop while drilling. If the fluid level in the well bore cannot be maintained, contingency plans should be in place to immediately start filling the annulus with seawater. 4. Loss circulation pills should be prepared prior to drilling. These pills should be pumped in the event losses develop. 5. Hydrostatic pressures in the well bore must be maintained above formation pore pressures at all times. As a guideline a minimum 0.5 ppg above formation pressure should be maintained. M-17 Drilling Program - AOGCC Page 6 . . 6. The trip tank will be monitored on every trip in and out of the hole. Both the mud loggers and the rig floor should maintain independent trip sheets from independent sources in the trip tank. 7. A Unocal Drilling Supervisor should be on the rig floor at the start of each trip to ensure the well is taking the correct fill. The Supervisor should remain on the floor until the well is stable and the drill string has been pulled into cased hole. M-17 Drilling Program - AOGCC Page 7 . . DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: 1. Weld starting head onto existing 28" conductor. 2. Skid rig to SW platform leg. 3. Rig up mud logging unit and redundant pit monitoring equipment. Rig Operations: 1. Nipple up diverter spool, riser and twin 16" diverter lines. PU 5" DP and HWDP as required and stand back in derrick. Test diverter line. 2. MU 17-1/2" BHA assembly and cleanout conductor to shoe depth at approximately 480' RKB. RU gyro and directionally drill surface hole to approximately 847' TVD. (see BHI directional plan). 3. Run and cement the 13-3/8". 68# L-80 surface casing back to surface. Provision will be made to execute a top job if cement does not remain at surface. 4. ND diverter system and complete NU of wellhead system. NU 16-3/4" 10M BOPE and test to 3000 psi. 5. MU 12-114" drilling assembly MWD/LWD (see page 4) and RIH to float collar. Test the 13-3/8" casing to 3000 psi for 30 minutes. Drill out shoe joints and drill new formation to 20' below 13-3/8" shoe and perform Leak Off Test. (Commence mud logging sample collection.) 6. Drill ahead to intermediate casing point at 1391' MD (1350' TVD). A wiper trip to surface will be performed prior to pulling out of the hole to run casing. 7. Run and cement the 9-5/8",40# L-80 intermediate casing back to surface. 8. MU 8-1/2" drilling assembly and MWD/LWD (see page 4) and RIH to float collar Drill out shoe joints and displace well to 8.6 ppg KCL Polymer drilling fluid. Drill new formation to 20' below 9-5/8" shoe and perform Leak Off Test. 9. Drill ahead to intermediate casing point at 5497' MD (4750' TVD). A wiper trip to surface will be performed prior to pulling out of the hole. 10. RU APRS/Precision and run Quad Combo log. Run Precision MFT formation pressure tester via drillpipe shuttle Perform wiper trip and POOH to run casing. 11. Run and cement the 7". 26# L-80 intermediate casing back to 200' inside the 9-5/8" casing. 12. MU 6-1/8" drilling assembly and RIH to float collar picking up 3-1/2" DP. Test the 7" casing to 3000 psi for 30 minutes. Drill out shoe joints and drill new formation to 20' below 7" shoe and perform Leak Off Test. 13. Drill ahead to TD at - 6032' TVD SS allowing enough rat hole to log the D14 sand. Condition hole for logging program. 14. RU Schlumberger and run Quad Combo log. Run Precision MFT formation pressure tester via wireline. Perform wiper trip and POOH to run liner. 15. Run and cement the 3-1/2" production liner as required. Displace the cement with filtered seawater plus 3% KCL and displace from the TOL to surface with filtered seawater plus 3% KCL after setting the liner top packer. 16. Run the 3-1/2", 9.2#, L-80 completion assembly with TRSSSV. Circulate around corrosion inhibitor. Sting seal assembly into tieback receptacle and test both the tubing and annulus to 3000 psi for 30 minutes. Release tubing pressure. 17. Install TWC and test to 1000 psi. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC and install BPV. Rid down and move off. Post Rig Operations: 1. Well will be perforated after rig release. M-17 Drilling Program - AOGCC Page 8 . . M-17 Drilling Program MIRU Hazards and Contingencies ~ Gas produced from the Grayling gas sands have contained no significant levels of H2S. The Steel head facility however requires that all safety equipment and procedures for dealing with H2S gas be in effect. Standard Operating Procedures for H2S environments should be followed at all times. Refer to Steel head H2S Contingency Plan. ~ During the last grassroots drilling campaign on Steel head (M-12), the bridge crane failed while nippling up the diverter equipment. Double check to ensure bridge crane operates correctly. ~ The diverter valves have not been used since 2001. Have spares available to redress valves should they develop leaks during diverter function test. ~ The standby CISPRI boat should be notified of our intention to spud a well on Steelhead platform. The vessel should remain in the area while the surface hole is being drilled as an evacuation contingency. ~ A Rig Floor ESD device will be installed and function tested prior to commencement of drilling. ~ Refer to attached Pre-Spud Checklist for additional precautions. Clean Out Conductor- Drill 17-1/2" Surface Hole Hazards and Contingencies ~ Observe returns inside conductor for contaminated fluids. Be prepared to divert fluid to surface tanks if necessary. ~ Care should be taken while working the drilling assembly through the conductor as there is a possibility it may be crimped or have surface junk inside. ~ Complete Diverter Mode Checklist (attached) to confirm proper operation of main and remote diverter panels. ~ There are three Close Approach issues with this hole interval: Offset Well Close Approach Analysis M-13 5' at conductor shoe diverging to 22' at 800' MD M-14 8' at conductor shoe diverging to 24' at 750' MD M-15 5' at conductor shoe diverging to 21' at 900' MD **A gyro run on e-line will be used to mitigate close approach issues during the kick-off. ~ Monitor close approach wells while drilling by stationing a Production Operator in the wellhead room to monitor casing annuli or listen for evidence of well bore collision. Review attached "Proximity Concerns for Steelhead M-17". If at any time during the kick-off, the close approach values become less than that indicated in the Close Approach Analysis above, M-17 Drilling Program - AOGCC Page 9 . . drilling will be halted and the well (s) which are of immediate concern will have a deep downhole tubing plug set, pressure bled off and SSSV closed. The well will remain shut in until safe to place back on production. > A mud logging unit will be fully rigged up and operational prior to drilling the 17-1/2" hole section. Mud loggers will supply redundant monitoring of the pit volumes, trip tank and well drilling parameters for the entire well. ~ Have materials on hand to quickly prepare LCM pills. Offset wells have experienced losses while drilling this hole section of up to 120bb/hr. ~ DSM and/or Toolpusher will be on rig floor at all times during the drilling, tripping, running casing and cementing operations of the surface hole section. Install 13-3/8" Surface Casina Hazards and Contingencies > It is critical that cement is circulated to surface for well integrity. Plan 200% excess lead slurry cement at 11.0 ppg and once observed at surface, pump tail cement at 15.8 ppg at 50% excess. > Verify that Schlumberger have on-hand ±250 sacks of lead cement in case a top job is required. > Two 6" side outlets will be installed below the 20" wellhead flange. Water jets will be installed in the overboard lines to prevent plugging while over-boarding cement. > Mandrel hanger maximum 00 including pack-off is 20.109". Ensure all diverter and riser components will drift. > The wellhead has a 3" access line for use in the event a top job is required. Drillina 12-1/4" Intermediate Hole Hazards and Contingencies A heightened awareness of kick detection, swab and surge, trip tank monitoring will be essential while drilling/tripping this interval. Special care must be taken not to drill below 1504' TVD as there is an overpressured interval which requires adequate casing shoe integrity to prevent the possibility of broaching to the mudline. > Kick Tolerance: Assuming gauge hole, a fracture gradient of 10.7 ppg at the 13-3/8" casing shoe, 9.2 ppg mud in the hole the kick tolerance is greater than 25 bbls. (Offset well M-12 had a LOT of 12.2 ppg at this shoe depth.) Contact Drilling Superintendent if LOT is less than 10.7 ppg. > Review the "Special Precautions to Ensure Well Control on Steelhead Platform" at the front of this program. > There is one Close Approach issue with this hole interval: Offset Well M-15 Close Approach Analysis 21' at 13-3/8" shoe diverging to 154' at 1500' MD **A gyro run on e-line will be used to mitigate close approach issues to approximately 1200'. M-17 Drilling Program - AOGCC Page 10 . . ~ The annular element on the 16-3/4" BOP was changed out in November 2001. Ensure replacement BOPE ram rubbers are available to re-dress the BOPE for both 5" and 3-1/2" drill pipe. Install 9-5/8" Intermediate Casina Hazards and Contingencies ~ It is critical that cement is circulated to surface for well integrity. Plan 150% excess lead slurry cement at 12.0 ppg and once observed at surface, pump tail cement at 15.8 ppg. Drillina 8-1/2" Intermediate Hole Hazards and Contingencies A heightened awareness of kick detection, swab and surge, trip tank monitoring will be essential while drilling/tripping through the shallow overpressured SZ11 interval. ~ Shallow Overpressure: The maximum anticipated reservoir pressure which will be penetrated in the 8-1/2 hole section has been estimated at 657 psi at 1344' TVD ss. This equates to a 9.4 ppg EMW or 8.4 ppg MW relative to the Steel head RKB. Special note: If the BOP stack is drained to the wellhead depth (78' RKB) a 8.9 ppg MW is the absolute minimum mud weight required in the hole to prevent an underbalance condition. ~ Kick Tolerance: Assuming gauge hole, a fracture gradient of 10.8 ppg at the 9-5/8" casing shoe, 9.2 ppg mud in the hole, the kick tolerance is greater than 25 bbls. Offset well had the following FIT/LOT's results: M-12, (13.5 ppg FIT), M-13, (12.1 ppg LOT), M-14 (12.8 ppg LOT), M-15 (11.5 ppg FIT?). Contact Drilling Superintendent if LOT is less than 10.8 ppg. Contact Drilling Superintendent if LOT is less than 10.8 ppg. ~ Lost circulation is considered a significant risk due to the subnormal reservoir pressures being drilled. Formation pressures will vary from 1.7 ppg to 8.7 ppg.The KCL Polymer mud system will be as much as 1600 psi over balance to the formation. The BHA will include a 6-3/4" Centurion circulating sub for use in spotting high concentrations of LCM materials should losses become excessive. ~ If full returns are lost while drilling and there is insufficient mud to maintain a fluid level at surface, the BOP's will be closed allowing time to mix and pump a LCM pill to slow losses. A significant loss of hydrostatic head will enable the overpressured sand body at 1344'TVDss to flow. ~ A significant number of coals will be penetrated in this hole interval. The interval should be reamed back through before drilling in excess of 10' of coal. ~ There is one Close Approach issue with this hole interval: Offset Well Close Approach Analysis M-15 154' at 9-5/8" shoe, 93' at 4275'MD. Ellipse separation is 36' at 4275' MD. M-17 Drilling Program - AOGCC Page 11 . . Intermediate Hole Loaaina Hazards and Contingencies ~ Differential sticking is a major concern. Formation pressures will vary from 1.7 ppg to 8.7 ppg. The KCL Polymer mud system will be as much as 1600 psi overbalance to the formation. Minimize the time the logging tools remain stationary. ~ Formation pressure testing tools will be conveyed through drill pipe due to differential sticking concerns. The "Precision" conveyance system will allow us to rotate and reciprocate the drillstring while obtaining pressure measurements. ~ As a contingency should the logging tools become stuck have "Strip and Cut" as well as fishing equipment sourced. Case & Cement 7"lntermediate Hole Hazards and Contingencies ~ The interval is planned to be cemented with a lead and tail slurry. The 15.8 ppg tail slurry will cover the shoe to the primary A2 target sand at 2711' TVD. The 12.5 ppg lead slurry will extend to 200' inside the 9-5/8" casing shoe. The slurries will include CemNET as a loss countermeasure. Once the hole interval has been drilled a decision will be made as to whether it would be prudent to reduce the 15.8 ppg cement coverage and supplement with additional 12.5 ppg slurry to reduce the exposure to losses. ~ The casing will be run at a reduced rate as described in the "Operational Specifics" to reduce the chances of losses or fracturing the depleted sands prior to the cement job. ~ Differential sticking is a major concern. Formation pressures will vary from 1.7 ppg to 8.4 ppg. The KCL Polymer mud system will be as much as 1600 psi overbalance to the formation Every attempt should be made to condition the hole and wiper trip sufficiently prior to running casing, ensure very tight fluid loss properties of the mud and that during casing running every effort must be made to keep the pipe moving. Drill 6-1/8" Production Hole Hazards and Contingencies ~ There are no "close approach" issues within the production hole interval. ~ Lost circulation is considered a significant risk due to the subnormal reservoir pressures being drilled. Formation pressures will vary from 3.4 ppg to 8.6 ppg. The KCL Polymer mud system will be as much as 1460 psi over balance to the formation. The BHA will include a circulating sub for use in spotting high concentrations of LCM materials should losses become excessive. ~ Kick Tolerance: Assuming gauge hole, a fracture gradient of 10.7 ppg at the 7" casing shoe, 9.2 ppg mud in the hole the kick tolerance is greater than 25 bbls. Contact Drilling Superintendent if LOT is less than 10.7 ppg. M-17 Drilling Program - AOGCC Page 12 . . Production Hole Loaaina Hazards and Contingencies ).> Differential Sticking: The KCL Polymer mud system will be as much as 1460 psi overbalance to the formation. Minimize the time the logging tools remain stationary. ).> If the tools are run through drill pipe due to our inability to reach bottom on e-line, the "Precision" conveyance system will allow us to rotate and reciprocate the drillstring during the logging operation. ).> As a contingency should the logging tools become stuck have "Strip and Cut" as well as fishing equipment sourced. Install 3%" Production Liner Hazards and Contingencies ).> The KCL Polymer mud system will be as much as 1460 psi over balance to the formation. Minimize the time the pipe is left stationary while running the liner. ).> Cement volume is 50% over theoretical hole volume. Adjust cement volume upwards if open hole logging data indicates additional cement is required. Job 12: Run Completion Hazards and Contingencies ).> Well Integrity: The annulus above the ZXP packer will be tested to 3000 psi to verify annulus integrity. A TWC will be installed and tested to 1000 psi prior to nippling down the BOP's. Job 13: ND/NU/Release Ria Hazards and Contingencies ).> No hazards specific to this well have been identified for this phase of the well construction. M-17 Drilling Program - AOGCC Page 13 . . Cement Calculations: Alaska Oil as Cons. CommiuÞ:JO Anchorage Casin Size 13-3/8" Surface Basis: Lead: Based on 410' of 28" conductor, 114' of open hole volum Lead TOC: To surface at 78' RKB Tail: Based on 250' open hole volume @ 50% excess + 80' Tail TOC: At -602' MD Total Cement Volume: Lead 261 bbl/1464ft 1440 sks f Dowell CemNET "G" blend at 11.0 and 3.33 cfls . 41 bbll 230 ft I 200 sk of Dowell CemNET "G" blend at 15.8 and 1.17 cfl . Tail Tail 85 bbll 12.0 26.8 1/151 ft 1128 sks of Dowell CemNET 'G' blend with ASBLOK at 15.8 and 1.17 cf/sk. Casin 9-5/8" Intermediate Longstring Basis: Lead: Based on 410' of 27" x 9-5/8" conductor nnulus, 291' of 9-5/8" x 12-1/4" annulus @150% excess Lead TOC: To surface at 78' RKB Tail: Based on 250' MD open hole volume 50% excess + 80' shoe track volume. Tail TOC: At -1141' MD Total Cement Volume: Lead Casin Size 7" Production Longstri g Basis: Lead: Based on TOC 200' ove 9-5/8" casing shoe at 1391' MD. 50% excess in open hole from 3360' to 1513' Tail: Based on cement fr m TD at 5497 (4750' TVD) to 3360'MD (To cover A2 sand at 2700' TVD + 50% exc s + 80' shoe track volume. Total Cement Volume: ead 68 bbl/382 ft 1180 sks of Dowell CemNET G blend at 12.5 'G' and 2.12 cf/sk. Tail 75.3 bbll 422 ft I 364 sks of Dowell CemNET 'G' blend at15.8 and 1.16 cf/sk. 3-1/2" Production Liner Le : Based on cement from TO at 6779' to the liner top at 5247' MD plus 3-1/2" D x 7" casing annulus to 5100' MD. Open hole volume from 7" shoe to TD at 0% excess + 40' shoe track volume. Volume: 55 bbll 308 ft I 265 sks of Dowell Premium 'G' at 15.8 ppg and 1.16 cf/sk f=3ê>~- \ ~ \Q~"'sc-d ~J~ ~ M-17 Drilling Program - AOGCC Page 4 . . Well Control: Surface hole will be drilled with diverter. The diverter system consistsAlfts~~&''''aJ: .~missíoi1 annular preventer, a 30" x 500 psi riser and two 16" diverter lines with hydraulicAH ~ted ball valves. The intermediate and production hole well control equipment will consis of fó',åoo psi working pressure blowout preventer stack outfitted with pipe rams(2), blind ra , and annular preventer. Based upon the maximum anticipated surface pressure the P equipment will be tested to 3000 psi. BOP equipment will be tested on a 14 day asis. Diverter, BOPE and drilling fluid system schematics on file with the Production Interval- · Maximum anticipated BHP: · Maximum surface pressure: 8.6 ppg EMW, 2640 psi 2421 psi @ surface ~ (based on 2640 psi at 4 and a full column of gas @ 0.10 psi/ft) · Planned BOP test pressure: · Planned completion fluid: 3000 psi / 8.6 ppg filtere Disposal: · Cuttings Handling: Cuttings gen ated from drilling operations will be discharged overboard as per NPDES Permit · Fluid Handling: Drilling and completion fluids will be discharged overboard as applicable under NPDES Permi H2S: · Gas produced from th Grayling gas sands have contained no significant levels of H2S. The Steel head facili however requires that all safety equipment and procedures for dealing with H2S 5 be in effect. M-17 Drilling Program - AOGCC Page 5 . . §pecial Precautions to Ensure Well C~J:J'KED Steel head Platform APR 2 9 2005 Alaska Oil & Gas Co . Commission In December 1987 the Steel head M-26 blew out which resulted in a ~Pêh ~8eexplosion which caused extensive damage to the platform. The primary reason for: e blowout was due to the unloading of a shallow gas sand at 2040' as a result an underbalance wellbore created during the pumping of a 200 bbl unweighted ter spacer prior to cementing the 13-3/8" casing. The reduction in hydrostatic p ssure resulted in an underbalance of approximately 20 psi over the highly perme Ie AD-2 and AD-4 gas sands. The well was placed on the diverter once the influx as noted, however it was estimated that the well was unloading in a rate in excess 0 'OOMMCFD and the surface diverting equipment soon failed. The post well review by a Marathon investigative p, rty determined that cause of the blowout was as follows: "The primary cause of the blowout on well M-26 as a casing program that did not allow the well to be restricted or shut off during a ki ,and relied on a diverter system for well control. A diverter is not a well control syste ,it is only a method to allow gas kicks to be temporarily released overboard, allowing ersonnel to be safely evacuated. If sufficient casing had been installed before drilling he shallow gas sands, it is unlikely that, even with the noted kick, a blowout would ha e occurred on well M-26". The well programs since that time h ve incorporated an additional casing string such that a BOP stack is in place prior to dr' Ing these prolific gas sands which commence at approximately 1500'. In addition xtensive modifications have been made to the surface diverter system to handle larg discharge volumes. Still additional precautions must be taken to ensure that the drilli g of the shallow gas sands in M-17 can be done in a safe manner. 1. Cement space and washes must be maintained at densities that will prevent well kicks. 2. Mud pro rties will minimize swab and surge pressures. Trip speed will be to minimize the effects of these pressures. 3. The uid level in the wellbore should not be allowed to drop while drilling. If the flu' level in the wellbore cannot be maintained, contingency plans should be in p, ce to immediately start filling the annulus with seawater. 4. Loss circulation pills should be prepared prior to drilling. These pills should be pumped in the event losses develop. Hydrostatic pressures in the wellbore must be maintain~d above formation pore pressures at all times. As a guideline a minimum 0.5 ppg above formation pressure should be maintained. M-17 Drilling Program - AOGCC Page 6 . . 6. The trip tank will be monitored on every trip in and out of the hole. Both the mud loggers and the rig floor should maintain independent trip sheets from independent sources in the trip tank. 7. A Unocal Drilling Supervisor should be on the rig floor at the start of each trip to ensure the well is taking the correct fill. The Supervisor should remain on the flo r until the well is stable and the drill string has been pulled into cased hole. ED Þ.PR · 9 2005 Alaska Oil & as Cons. Commission Anchorsge M-1?' Drilling Program - AOGCC Page 7 . . RECEIV D DRILL AND COMPLETE PROCEDURE SUMMAR~R 2 2005 Pre-Rig Work: 1. Weld starting head onto existing 28" conductor. 2. Skid rig to SW platform leg. 3. Rig up mud logging unit and redundant pit monitoring equipment. s Cons. Commission nchorage Rig Operations: 1. Nipple up diverter spool, riser and twin 16" diverter lines. PU 5" DP and HWDP back in derrick. Test diverter line. 2. MU 17-1/2" BHA assembly and cleanout conductor to shoe depth at appro' ately 480' RKB. RU gyro and directionally drill surface hole to approximately 847' TVD. (see BHI di ctional plan). 3. Run and cement the 13-3/8", 68# L-80 surface casing back to su ceo Provision will be made to execute a top job if cement does not remain at surface. 4. ND diverter system and complete NU of wellhead system. NU 6-3/4" 10M BOPE and test to 3000 psi. / 5. MU 12-1/4" drilling assembly MWD/LWD (see page 4) and IH to float collar. Test the 13-3/8" casing to 3000 psi for 30 minutes. Drill out shoe joints and drill w formation to 20' below 13-3/8" shoe and perform Leak Off Test. (Commence mud logging sampl collection.) .,/ 6. Drill ahead to intermediate casing point at 1391' (1350' TVD). A wiper trip to surface will be performed prior to pulling out of the hole to run cas' g. 7. Run and cement the 9-5/8", 40# L-80 intermedia casing back to surface. /' 8. MU 8-1/2" drilling assembly and MWD/LWD ee page 4) and RIH to float collar Drill out shoe joints and displace well to 8.6 ppg KCL Polymer rilling fluid. Drill new formation to 20' below 9-5/8" shoe and perform Leak Off Test. 9. Drill ahead to intermediate casing poi t at 5497' MD (4750' TVD). A wiper trip to surface will be performed prior to pulling out of the h e. ./ 10. RU APRS/Precision and run Qua Combo log. Run Precision MFT formation pressure tester via drillpipe shuttle Perform wiper trip, nd POOH to run casing. 11. Run and cement the 7",26# L- intermediate casing back to surface. 12. MU 6-1/8" drilling assembly nd RIH to float collar picking up 3-1/2" DP. Test the 7" casing to 3000 psi for 30 minutes. Drill 0 shoe joints and drill new formation to 20' below 7" shoe and perform Leak Off Test. required and stand 13. Drill ahead to TD at - 032' TVD SS allowing enough rat hole to log the D14 sand. Condition hole for logging program. 14. RU Schlumberger and run Quad Combó log. Run Precision MFT formation pressure tester via wireline. Perform iper trip and POOH to run liner. 15. Run and cem t the 3-1/2" production liner as required. Displace the cement with filtered seawater plus 3% KC and displace from the TOL to surface with filtered seawater plus 3% KCL after setting the liner top acker. 16. Run the -1/2", 9.2#, L-80 completion assembly with TRSSSV. Circulate around corrosion inhibitor. Sting s I assembly into tieback receptacle and test both the tubing and annulus to 3000 psi for 30 minut . Release tubing pressure. 17. Inst I TWC and test to 1000 psi. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Rove TWC and install BPV. Rid down and move off. Po Rig Operations: 1. Well will be perforated after rig release. M-17 Drilling Program - AOGCC Page 8 . . M-17 Drilling Program Gas Cons. CommiS8ìon Anchorage MIRU Hazards and Contingencies ~ Gas produced from the Grayling gas sands have contained no gnificant levels of .,. H2S. The Steel head facility however requires that all s ty equipment and procedures for dealing with H2S gas be in effect. Standar Operating Procedures for H2S environments should be followed at all times. efer to Steel head H2S .,.. Contingency Plan. ~ During the last grassroots drilling campaign on Steelhead ( -12), the bridge crane failed while nippling up the diverter equipment. Double check to ensu bridge crane operates correctly. ~ The diverter valves have not been used since 2001. ve spares available to redress valves should they develop leaks during diverter function t t. ~ The standby CISPRI boat should be notified of 0 intention to spud a well on Steel head platform. The vessel should remain in the area while the urface hole is being drilled as an evacuation contingency. ~ A Rig Floor ESD device will be installed a function tested prior to commencement of drilling. ~ Refer to attached Pre-Spud Checklist or additional precautions. Clean Out Conductor- Drill 17- 2" Surface Hole Hazards and Contingencie ~ Observe returns inside onductor for contaminated fluids. Be prepared to divert fluid to surface tanks if necessary. ~ Care should be ta n while working the drilling assembly through the conductor as there is a possibility it may e crimped or have surface junk inside. ~ Complete Dive er Mode Checklist (attached) to confirm proper operation of main and remote diverter pane . ~ There are ree Close Approach issues with this hole interval: Offset Well Close Approach Analysis M-13 5' at conductor shoe diverging to 22' at 800' MD M-14 8' at conductor shoe diverging to 24' at 750' MD M-15 5' at conductor shoe diverging to 21' at 900' MD **A gyro run on e-line will be used to mitigate close approach issues during the kick-off. Monitor close approach wells while drilling by stationing a Production Operator in the wellhead room to monitor casing annuli or listen for evidence of wellbore collision. Review attached "Proximity Concerns for Steel head M-17". M-17 Drilling Program - AOGCC Page 9 . . ~ A mud logging unit will be fully rigged up and operational prior to drilling the 17-1/2" hole section. Mud loggers will supply redundant monitoring of the pit volumes, trip tank and well drilling parameters for the entire well. > Have materials on hand to quickly prepare LCM pills. Offset wells have experienced losses w . e drilling this hole section of up to 120bb/hr. > DSM and/or Toolpusher will be on rig floor at all times during the drilling, trippin~runn' and cementing operations of the surface hole section. t( ash Oil & Gas Cons. Commission Anchorage Install 13-3/8" Surface Casina Hazards and Contingencies ~ It is critical that cement is circulated to surface for well integrity. Ian 200% excess lead slurry cement at 11.0 ppg and once observed at surface, pump tail ment at 15.8 ppg at 50% excess. ~ Verify that Schlumberger have on-hand ±250 sacks of Ie cement in case a top job is required. ~ Two 6" side outlets will be installed below the 20" well ad flange. Water jets will be installed in the overboard lines to prevent plugging while over-b rding cement. ~ Mandrel hanger maximum 00 including pack-off' 20.109". Ensure all diverter and riser components will drift. ~ The wellhead has a 3" access line for use in e event a top job is required. /" Drillina 12-1/4" Intermediate Hole Hazards and Contingencies A heightened awareness f kick detection, swab and surge, trip tank monitoring will be essential while drilling/¡ ipping this interval. Special care must be taken not to drill below 1504' TVD as there is n overpressured interval which requires adequate casing shoe /" integrity to prevent e possibility of broaching to the mudline. ~ Kick Tolerance: suming gauge hole, a fracture gradient of 10.7 ppg at the 13-3/8" casing shoe, 9.2 ppg mud in t e hole the kick tolerance is greater than 25 bbls. (Offset well M-12 had a LOT of /' 12.2 ppg at thi shoe depth.) Contact Drilling Superintendent if LOT is less than 10.7 ppg. ~ Review the" pecial Precautions to Ensure Well Control on Steel head Platform" at the front of this program. ~ There i one Close Approach issue with this hole interval: Offset Well Close Approach Analysis M-15 21' at 13-3/8" shoe diverging to 154' at 1500' MD A gyro run on e-line will be used to mitigate close approach issues to approximately 1200'. The annular element on the 16-3/4" BOP was changed out in November 2001. Ensure replacement BOPE ram rubbers are available to re-dress the BOPE for both 5" and 3-1/2" drill pipe. M-17 Drilling Program - AOGCC Page 10 . . Install 9-5/8" Intermediate Casina RECEIVED APR 2 9 2005 Araska Oil & Gas Cons. Commission Anchorage ~ It is critical that cement is circulated to surface for well integrity. Plan 150% excess lead slurry cement at 12.0 ppg and once observed at surface, pump tail cement at 15.8 ppg. Hazards and Contingencies Drillina 8-1/2" Intermediate Hole Hazards and Contingencies A heightened awareness of kick detection, swab and surge, trip nk monitoring will be essential while drilling/tripping through the shallow over pres red SZ11 interval. / ~ Shallow Overpressure: The maximum anticipated reservoir ressure which will be penetrated in ,.- the 8-1/2 hole section has been estimated at 657 psi at 13 'TVD ss. This equates to a 9.4 ppg ...- EMW or 8.4 ppg MW relative to the Steel head RKB. Special note: If the BOP stack is drained to t wellhead depth (78' RKB) a 8.9 ppg MW is the absolute minimum mud weight requir: d in the hole to prevent an underbalance condition. ~ Kick Tolerance: Assuming gauge hole, a fra ure gradient of 10.8 ppg at the 9-5/8" casing shoe, 9.2 ppg mud in the hole, the kick tolerance' greater than 25 bbls. Offset well had the following FIT/LOT's results: M-12, (13.5 ppg FIT), -13, (12.1 ppg LOT), M-14 (12.8 ppg LOT), M-15 (11.5 ppg FIT?). Contact Drilling Superintend t if LOT is less than 10.8 ppg. Contact Drilling Superintendent if LOT is less than 10 ppg. ~ Lost circulation is considered a sig Ificant risk due to the subnormal reservoir pressures being drilled. Formation pressures will ry from 1.7 ppg to 8.7 ppg.The KCL Polymer mud system will be as much as 1600 psi over b ance to the formation. The BHA will include a 6-3/4" Centurion circulating sub for use in spo ng high concentrations of LCM materials should losses become excessive. ~ If full returns are lost whi drilling and there is insufficient mud to maintain a fluid level at surface, the BOP's will be close allowing time to mix and pump a LCM pill to slow losses. A significant loss of hydrostatic he ä will enable the overpressured sand body at 1344'TVDss to flow. ~ A significant numb of coals will be penetrated in this hole interval. The interval should be reamed back thr gh before drilling in excess of 10' of coal. ~ There is one C se Approach issue with this hole interval: Close Approach Analysis 154' at 9-5/8" shoe, 93' at 4275'MD. Ellipse separation is 36' at 4275' MD. Inter ediate Hole Lo in Ha rds and Contingencies ~ Differential sticking is a major concern. Formation pressures will vary from 1.7 ppg to 8.7 ppg. The ./ KCL Polymer mud system will be as much as 1600 psi overbalance to the formation. Minimize the time the logging tools remain stationary. M-17 Drilling Program - AOGCC Page 11 . . ~ Formation pressure testing tools will be conveyed through drill pipe due to differential sticking concerns. The "Precision" conveyance system will allow us to rotate and reciprocate the drillstring while obtaining pressure measurements. ~ As a contingency should the logging tools become stuck have "Strip and Cut" as well as fishi equipment sourced. o APR 2 9 2005 Case & Cement 7"lntermediate Hole Alaska Oil & Gas Cons. CommissIOn Hazards and Contingencies ~ The interval is planned to be cemented with a lead and tail slur he 15.8 ppg tail In.Fþ~"ge cover the shoe to the primary A2 target sand at 2711' TVD. T 12.5 ppg lead slurry will extend to 200' inside the 9-5/8" casing shoe. The slurries will include emNET as a loss countermeasure. Once the hole interval has been drilled a decision will be ade as to whether it would be prudent to reduce the 15.8 ppg cement coverage and supplem t with additional 12.5 ppg slurry to reduce the exposure to losses. ~ The casing will be run at a reduced rate as descri d in the "Operational Specifics" to reduce the chances of losses or fracturing the depleted sa s prior to the cement job. ~ Differential sticking is a major concern. For tion pressures will vary from 1.7 ppg to 8.4 ppg. The KCL Polymer mud system will be as much s 1600 psi overbalance to the formation Every attempt should be made to condition the ole and wiper trip sufficiently prior to running casing, ensure very tight fluid loss properties 0 he mud and that during casing running every effort must be made to keep the pipe moving. ~ There are no "close pproach" issues within the production hole interval. ~ Lost circulation is onsidered a significant risk due to the subnormal reservoir pressures being drilled. Formati pressures will vary from 3.4 ppg to 8.6 ppg. The KCL Polymer mud system will be as much a 1460 psi over balance to the formation. The BHA will include a circulating sub for use in spotti high concentrations of LCM materials should losses become excessive. ~ Kick Tole nee: Assuming gauge hole, a fracture gradient of 10.7 ppg at the 7" casing shoe, 9.2 ppg mu n the hole the kick tolerance is greater than 25 bbls. Contact Drilling Superintendent if LOT is ss than 10.7 ppg. Drill 6-1/8" Production Hole Hazards and Contingencie Produ lion Hole Lo in Haz ds and Contingencies Differential Sticking: The KCL Polymer mud system will be as much as 1460 psi overbalance to the formation. Minimize the time the logging tools remain stationary. M-17 Drilling Program - AOGCC Page 12 . . >- If the tools are run through drillpipe due to our inability to reach bottom on e-line, the "Precision" conveyance system will allow us to rotate and reciprocate the drillstring during the logging operation. >- As a contingency should the logging tools become stuck have "Strip and Cut" as well as fishin equipment sourced. Install 3%" Production Liner Alask íl & Gas Cons. Commission Hazards and Contingencies Anchor~ge >- The KCL Polymer mud system will be as much as 1460 psi 0 r balance to the formation. Minimize the time the pipe is left stationary while running the liner. >- Cement volume is 50% over theoretical hole volume. Adjust ment volume upwards if open hole logging data indicates additional cement is required. Job 12: Run Completion Hazards and Contingencies >- Well Integrity: The annulus above the ZXP acker will be tested to 3000 psi to verify annulus integrity. A TWC will be installed a éI tested to 1000 psi prior to nippling down the BOP's. Job 13: ND/NUlRelease i Hazards and Con tinge cies >- No hazards spe ic to this well have been identified for this phase of the well construction. M-17 Drilling Program - AOGCC Page 13 SteelheadPlatform Wen No. 17 Proposed Completion RKB to TBG Head = 75.00' SIZE 28" 13-3/8" 9-5/8" 7" 3-1/2" Tubin 3-1/2" CASING AND TUBING DETAIL GRADE CONN MIN lD Structural 27" L-80 BTC 12.415 L-80 BTC 8.679 L-80 BTC-M 6.276 L-80 IBTM 2.992 BTM. 448' 850' 1391' 5497' 6779' TOP Surface Surface Surface Surface 5247' \VT 68 40 26 9.2 9,2 L-80 IBTM JEWELRY - NO. Depth lD OD Hem .w 75' VetcoGray Hanger Butt Down-EUE 8RD up 77' 2,992" 3-1/2" Butt x TDS Pin Down X/O 2,992" 5.968" 3-1/2" SFO-2 GLM's 2,992" 3-1/2" 9,2# L-80 IBT-m Tbg 450' 2,813" 5.20" Halliburton WelJstar TRSSSV 2,813 X nipple 5300' 2,99" 4,00" 3-1/2" Baker Seal Assembly and locator (8,0') 2,992 Baker y,. Mulshoe WLEG 5300' 7" x 5" Baker HMC with ZXP and 6' tieback extension various 2.813" X Nipples PERFORATION HISTORY Zone Top Dtm Date Comments PBTD =6,714' TD = 6,779' MAX HOLE ANGLE = 52° @ 2,000' Proposed Completion DRAWN BY: NM 4-22-05 82.18' Ce:nt~r of part on ìg s.ub 47,37' 6,50' 17.17 29.50' 7.17 3,05' Rig Sub Grating Floor Stack up to cent~r of port Qn Rig 47-48' 23.47' Needed For Nipple UP 21.07' 4~ each R-95 Ring Gaskets 2· each Dril-Quip OX Seal Rings 30" Spare Drill Quip Long & short Bolts 84 1 3/4" x 13" studs 168 23/4" x 1 3/4 Nuts (each etra of above for Flow nipple) Torque wrench, for 200 ft Ibs on on Oril-Quip Quick clam connector Diverter line Nipple up 160 each 1 1/2" x 10 1/4" Studs 320 each 2 3/8" x 1 1/2" Nuts 8 each 16" 600 flange gaskets Hydraulic line Hook up Choke line to Noth Diverter Valve Kill line to South Diverter Valve Annular ( Close) to annular Upper well bay room floor 17,04' Note: The 17,04 Ris.er sectiQn has mïn ID of 27,8125" due to some irregularity due tQ welding on of the 30" clamp Top of grating in well room 4.06' 22,88' Well head room floor I Kin Line " \ Choke Line Steelhead BOP Drawing ¿; ~ Steelhead Pit Drawing Mud Return Equalizer Agitator Mud Gun I Revised by MWD 9/17/99 STEELHEAD WELLSLOT DIAGRAM 05/01/01 M-27 M-29 Leg B-1 NW Corner Leg B- 2 NE Corner e . o ,; @ Producer Gas Well Injector 20" & 16" Csg Preset Dual Completion Leg A-1 SW Corner Leg A- 2 SE Corner :;;¡:;:;::.=- 0'1 3: o ~ w W f- (f) f- o -.J (f) -.J -.J W 3: ./ (J) -<-' o (J) Q) 3: ./ E I- o - -<-' o Q... ./ 0'1 c :.¡:; - o I- o ./ ..:J UNOCAL Location: TBU, Cook Inlet, Alaska Field: McArthur River Field Installation: STEELHEAD Platform reate y : lanner Date plotted: 4-Apr-2005 ot r erence IS -1 Ref wellpath Is M-17 V4. Coordinates are in feet reference slot #A 1-9, True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum, Rig Datum: Planned Datum Rig Datum to mean sea level: 160,25 It, Plot North is aligned to TRUE North, -= 0 -400 0 N II E 0 -0 Q) ro 0 en 400 800 1200 1600 Z" 2000 Q) .E - oS: 2400 ..... Co Q) C 2800 ñi CJ :e 3200 Q) > Q) 3600 ;:j &.. l- I V 4000 4400 4800 5200 5600 6000 6400 j l 28.000in Conductor KOP End of Hold 46,12 39.13 Target 28.00 23.00 13.00 8.00 3,00 Slot: Well: Well bore: -400 -0 400 800 1200 1600 2000 2400 Seale 1 em = 20VtØrtical Section (feet) .> ~ Azimuth 195.40 with reference 0.00 N, 0.00 E from slot #A1-9 1 \ 7.00 \::,. 13 3/8in Casing 13.71 20.54 DLS: 3.50 deg/100t! 9 5/8in Casing 34.40 41.37 48,34 EOC DLS: 2.50 deg/1 00t! End of Drop M-17 C5 (Primary) M-17 D3B (Primary) M-17 D6 (Primary) M-17 D14 (Primary) 3 1/2in Liner RECEIVED Seale 1 em = 80 ft East (feet)·> A P R 2 9 Z005 -800 -640 -320 -480 28.000in Conductor 13 3/8in Casing M-17 D6 (Primary) M-17 D3B (Primary) M-17 C5 (Primary) L 7.000in Casing l TD WELL PROFILE DATA Point Me Inc Azl lVe North East deg/100tt V. Sect Tie on 0,00 0,00 0,00 0.00 0,00 0,00 0,00 0,00 End of Hold 480,00 0,00 0,00 480,00 0,00 0,00 0,00 0,00 End of Hold 500,00 0,00 0,00 500,00 0,00 0,00 0,00 0,00 KOP 750,00 8,75 215,00 749,03 -15,81 ·10,93 3,50 17,95 End of BuildfTum 2046,79 53,46 193,69 1833,21 ·635,31 -200,83 3,50 665,83 End-of Hold 2789,91 53,46 193,89 2275,64 -1215.42 -342,14 0,00 1262,84 Target 3375.43 33,00 195,40 2700,00 ·1801,80 -441,21 3,50 1661.45 End of Drop 4695.43 0,00 195,40 3948,22 ·1958,26 -539,40 2,50 2031.19 T.O. & End of Hold 6779,38 0,00 195,40 8032,17 -1958,28 -539,40 0,00 2031,19 160 0 -160 -320 -480 -640 -800 ^ I Z 0 -960 ;::¡. ::r - CD' -1120 ~ - -1280 -1440 -1600 -1760 en n w ëÐ -1920 n 3 II -2080 CD 0 ;:1 ·' . u.jj~"'. UNOCAL ,slot #A1-9 STEELHEAD Platform, McArthur River Field,TBU, Cook Inlet, Alaska PROPOSAL LISTING Page 1 Wellbore: M-17~ Wellpath: M-171'O'\CCEf\1 Date Printed: 4-Apr-2~~ 6)!\ '10ns o . ¡..;,è,U Alaska Oil &. Ga;; All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Planned Datum 160,3ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 195.40 degrees Bottom hole distance is 2031.19 Feet on azimuth 195.40 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . . 11II.:11:"'. UNOCAL ,slot #A 1-9 STEELHEAD Platform, McArthur River Field,TBU, Cook Inlet, Alaska PROPOSAL LISTING Page 2 WeUbore: M-17 V4 WeUpath: M-17 V4 Date Printed: 4-Apr-2005 RECF~' 100,00 0.00 0.00 100.00 O,OON O.OOE 0.00 0,00 214070.15 v2499450,46 200.00 0.00 0,00 200.00 O.OON O.OOE 0.00 0.00 214070.15 2499450.46 300,00 0,00 0.00 300.00 O,OON O.OOE 0.00 0,00 214070.15 2499450.46 400.00 0.00 0.00 400.00 O,OON O.OOE 0.00 0,00 ' 214070.15 2499450,46 480.00 0.00 0.00 480,00 O.OON O.OOE 0,00 0.00 214070,15 2499450.46 500.00 0,00 0.00 500.00 O,OON O,OOE 0.00 0,00 214070,15 2499450.46 600.00 3.50 215.00 599.94 2.50S 1,75W 3.50 2.88 214068,34 2499448.00 700,00 7,00 215.00 699.50 9,995 7,OOW 3,50 11.50 214062.91 2499440.64 750.00 8.75 215.00 749.03 15.61S 10.93W 3.50 17.95 214058,85 2499435.13 800,00 10.37 211,01 798.33 22.585 15,43W 3.50 25.87 214054.18 2499428.27 900,00 13.71 205.89 896.12 40.965 25.24W 3.50 46.19 214043,92 2499410,13 1000,00 17,11 202,75 992.52 65,195 36,11W 3.50 72.44 214032.47 2499386,18 1100.00 20.54 200.64 1087.16 95.185 47.98W 3.50 104.51 214019,86 2499356.48 1200,00 23,99 199,11 1179,68 130.825 60.83W 3,50 142.28 214006.15 2499321.17 1300.00 27.46 . 197,95 1269.76 171.985 74.59W 3.50 185.61 213991,39 2499280.36 1400.00 30,93 197.02 1357,05 218.50S 89.22W 3.50 234.34 213975.62 2499234.21 1500.00 34.40 196,27 1441.22 270.20S 104.67W 3.50 288.30 213958,92 2499182,90 1600,00 37.88 . 195.64 . 1521.,96 326,915 120,87W 3.50 347.27 213941,34 2499126.61 1700,00 41,37 195,11 1598.97 388.395 137.76W 3.50 411.03 213922,95 2499065,55 1800.00 44.85 194.64 1671.96 454,445 155,29W 3.50 479.36 213903,81 2498999 96 1900.00 48,34 194,22 1740,66 524.795 173,39W 3,50 551.99 213884,00 2498930,07 2000,00 51.83 193.85 1804.82 599,195 191,98W 3.50 628.66 213863.60 2498856.15 2046,79 53.46 193,69 1833,21 635.315 200,83W 3.50 665.83 213853.87 2498820.25 2100.00 53.46 193,69 1864.89 676.85S 210.95W 0,00 708,57 213842.74 2498778.97 2200,00 53.46 . 193.69 1924.43 754,915 229,97W 0.00 788.88 213821.82 2498701.40 2300.00 53.46." 193,69 1983.96 832.975 248.98W 0.00 869,19 213800,91 2498623.82 2400,00 53.46 193,69 2043.50 911.04S 268,OOW 0.00 949.50 213779.99 2498546.25 2500.00 53.46 193,69 2103.04 989.105 287.01W 0.00 1029,81 213759,07 2498468.67 2600,00 53.46 193.69 2162.57 1067,165 306,03W 0.00 1110.12 213738.16 2498391 ,10 2700.00 53.46 193,69 2222,11 1145.235 325.04W 0.00 1190.43 213717.24 2498313,52 2789,91 53.46 193,69 2275.64 1215.425 342,14W 0.00 1262.64 213698.44 2498243.77 2800,00 53,11 193.71 2281,67 1223.275 344.06W 3.50 1270.72 213696.33 2498235.97 2900,00 49.61 193.92 2344,11 1299.115 362.70W 3.50 1348.78 213675,84 2498160.61 3000.00 46,12 194.16 2411,18 1371.04S 380.69W 3.50 1422,91 213656.10 2498089.14 3100,00 42.62 194.43 2482.66 1438.795 397,95W 3.50 1492.81 213637.19 2498021,83 3200.00 39,13 194.73 2558,26 1502,125 414.42W 3.50 1558.24 213619.18 2497958,93 3300,00 35.63 195.09 2637.71 1560,785 430,03W 3.50 1618.94 213602,14 2497900.67 3375.43 33,00 195.40 2700,00 1601.805 441.21W 3.50 1661.45 213589.96 2497859.93 3475,43 30.50 195,40 2785.03 1652.535 455,18W 2.50 1714.07 213574.75 2497809,56 3575.43 28,00 195.40 2872,27 1699.635 468,16W 2,50 1762.93 213560.63 2497762,79 3675.43 25,50 195.40 2961.56 1743.025 480,11W 2.50 1807,94 213547,63 2497719,70 3775.43 23.00 195.40 3052.73 1782.625 491,01W 2.50 1849.00 213535.76 2497680.38 3875.43 20.50 195.40 3145.61 1818.345 500,86W 2,50 1886,06 213525.05 2497644.91 3975,43 18.00 195,40 3240,01 1850,125 509,61W 2.50 1919.02 213515.52 2497613,35 4075.43 15.50 195.40 3335,76 1877.905 517,26W 2.50 1947,84 213507.19 2497585,77 4175.43 13.00 195.40 3432.67 1901,635 523,80W 2,50 1972.45 213500.08 2497562,20 4275.43 10,50 195.40 3530,57 1921,275 529.21W 2.50 1992.82 213494.19 2497542.71 4375.43 8,00 195.40 3629.26 1936.765 533,47W 2,50 2008.89 213489.55 2497527.32 4475.43 5.50 195.40 3728.56 1948,095 536,60W 2.50 2020.64 213486.15 2497516.07 4575,43 3,00 195.40 3828,28 1955.245 538.56W 2.50 2028,05 213484.01 2497508.98 All data is in Feet unless otherwise stated Coordinates are from 510t MO's are from Rig and TVO's are from Rig ( Planned Datum 160,3f1 above mean sea level) Vertical 5ection is from O.OON O,OOE on azimuth 195.40 degrees Bottom hole distance is 2031.19 Feet on azimuth 195.40 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . . 1!I,..dÎ;tB UNOCAL ,slot #A1-9 STEELHEAD Platform, McArthur River Field,TBU, Cook Inlet, Alaska PROPOSAL LISTING Page 3 Wellbore: M-17 V4 Well path: M-17 V4 Date Printed: 4-Apr-2005 RECEn/ED 4695.43 0,00 195.40 3948.22 1958.26S 539.40W 2.50 2031.19 213483.10 2497505,97 4700.00 0,00 195.40 3952.80 1958.265 539.40W 0.00 2031,19 213483,10 2497505.97 4800.00 0,00 195.40 4052.80 1958.265 539.40W 0,00 2031.19 213483.10 2497505.97 4900,00 0.00 195.40 4152.80 1958.26S 539.40W 0.00 2031.19 213483,10 2497505.97 5000.00 0,00 195.40 4252,80 1958,26S 539.40W 0.00 2031.19 213483.10 2497505,97 5100.00 0,00 195.40 4352,80 1958.265 539.40W 0,00 2031.19 213483.10 2497505.97 5200.00 0.00 195.40 4452.80 1958:26S 539.40W 0.00 2031.19 213483.10 2497505.97 5300,00 0,00 195.40 4552,80 1958.26S 539.40W 0.00 2031.19 213483.10 2497505.97 5400.00 0,00 195.40 4652,80 1958,265 539.40W 0.00 2031.19 213483.10 2497505.97 5500.00 0.00 195,40 4752.80 1958.26S 539,40W 0,00 2031.19 213483.10 2497505.97 5600.00 0.00 195.40 4852.80 1958.26S 539.40W 0,00 2031.19 213483,10 2497505.97 5700.00 0,00 195.40 4952,80 1958.265 539.40W 0.00 2031.19 213483.10 2497505.97 5800.00 0.00 195.40 5052.80 1958.265 539.40W 0,00 2031.19 213483,10 2497505.97 5900.00 0.00 195.40 5152.80 1958.265 539.40W 0,00 2031,19 213483,10 2497505.97 6000.00 0.00 195.40 5252.80 1958.265 539.40W 0.00 2031.19 213483.10 2497505,97 6100.00 0.00 195,40 5352.80 1958.26S 539.40W 0,00 2031.19 213483.10 2497505.97 6200.00 0,00 195.40 5452,80 1958,265 539.40W 0,00 2031.19 213483.10 2497505.97 6300,00 0.00 195.40 5552.80 1958.265 539.40W 0.00 2031.19 213483,10 2497505.97 6400.00 0.00 195.40 5652.80 1958.265 539,40W 0,00 2031.19 213483.1 0 2497505,97 6500.00 . 0.00 195.40 5752,80 1958,265 539.40W 0,00 2031,19 213483.10 2497505.97 6600.00 0.00 195.40 5852.80 1958.26S 539.40W 0.00 2031.19 213483.10 2497505.97 6700,00 0,00 195.40 5952.80 1958.265 539.40W 0.00 2031.19 213483.10 2497505.97 6779.38 0.00 195,40 6032,18 1958,265 539.40W 0.00 2031.19 213483.10 2497505.97 All data is in Feet unless otherwise stated Coordinates are from 510t MD's are from Rig and TVD's are from Rig ( Planned Datum 160,3f1 above mean sea level) Vertical 5ection is from O.OON O.OOE on azimuth 195.40 degrees Bottom hole distance is 2031.19 Feet on azimuth 195.40 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . . .1I.;C,*LfI UNOCAL ,slot #A1-9 STEELHEAD Platform, McArthur River Field,TBU, Cook Inlet, Alaska PROPOSAL LISTING Page 4 Wellbore: M-17 V4 Wellpath: M-17Dt::CE'\1 Date Printed: 4-ApP-2des~.J- fy APR 2 9 2005 O,OON 635.315 1215,425 1601,80S 1958,26S 1958.26S O.OOE 200.83W 342.14W 441,21W 539,40W 539,40W KOP EOC End of Hold Tar et End of Oro TO 1927,145 318.12W 5040,33 1943.935 327.53W 4767,96 N60 4935.45 W151 3615.24 N60 4935.29 W151 3615.43 213705.07 213695.25 2497531.68 2497515.13 1-Mar-2005 1-Mar-2005 1930.785 376.81W 4153.47 N60 4935.42 W151 3616.43 213646.31 2497529.48 1-Mar -2005 All data is in Feet unless otherwise stated Coordinates are from 510t MO's are from Rig and TVO's are from Rig (Planned Datum 160,3f1 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 195.40 degrees Bottom hole distance is 2031.19 Feet on azimuth 195.40 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated UNOCAL U"N'O' !_c_:::::; ~ :-:". ; .., ",.., .---'-' .,-->..- -_.,--,.,.,,: 300 Location: TBU, Cook Inlet, Alaska Field: McArthur River Field Installation: STEELHEAD Platform Slot: slot #A 1-9 Well: M-17 Wellbore: reated by : snner Date plotted: 28-Mar-2005 Plot reference is M~17 V4. Refwellpath is M-17 V4, Coordinates are in feet reference slot #A 1~9. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Planned Datum Rig Datum to mean sea leveL 160.25 ft. Plot North is aligned to TRUE North, 340 f'fiì W I , I I ¡ I I I 110 ¡ , ¡ I I I /1600 20 330 320 310 290 280 80 270 2 0 1 0 1 0 2 0 90 260 100 250 110 240 120 230 í ! / /220 .I 4500/ i ! / í ¡ r!J 130 140 210 150 200 160 190 180 170 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference W , . ""iIIi'M--.' ". ,.all , . . BAKER ,,'...' HUGHES INTEQ 20 -20 -40 ^ I - ã) -60 C» - - .s:::. -80 1: o Z -100 -= o -120 II E o -140 Q) ~ en -160 -150 -200 -250 I} -300 - ..... C» C» ~ -350 .s:::. 1: o -400 Z -450 -= I.C) N II -500 E o Q) ~ -550 en UNOCAL Location: TBU, Cook Inlet, Alaska Field: McArthur River Field Installation: STEELHEAD Platform Scale 1 em ;= 10 ftEast (feet) _> -100 -80 -60 -40 -26 0 20 o \ W If) .~ V \\ \ ''ò...-~~ ~~.....,:: ? 4!t" ~<09o;ðö 50 '650~00 \'~ ~_<~ "bo <to 650/.",.. 5250 , )"}q, ~'........:"';;' ~8JSO 100 I ~p50 ',7. ~ ........orÀ.........'Ó "tI \ ;:750 \2850 \9 ~ ~q, .......-....:;:..,~/.... "'~ \ 61: \ ísoo \2900 ~__~<:>..( 'ò '\ \ 800 /850 \'950 ,,_\~ /" ¡.'IIDO \ \'01' /..... iIò \ 850 \ 950 \ ~ '\ J\1000 ~ \ ~\8400 \ 950 A"00 \ \- 6150 \ \\ 1150' '\\ \ '000 /1 \ \ \~'''OO 1200//'150 \ \ , < '>JA/I \\"50 \ 1050 7/'200 ,\ o \\ /' i -\\ ! I"" \ 1100 .,'" I \\ / ! \ \ / \\ 1/"'" /t13'" 8500\ \ '150 ï. \ \ 1450 \ \8250 I,,,, \ \ ! \ \ / \ \ \~ "'0 Scale 1 em = 10ft '% -100 -80 -60 -40 -20 Ea~t (feet) -> -250 -200 -150 -100 -50 o 20 40 East (feet) -> o 50 Scale 1 em = 25 ft \ 8800 \ ~ \'0 \ \ ....\ \ 8700\ ~ -250 -200 -150 -100 -50 Scale 1 em = 25 ftEast (feet) -> o 40 20 o -20 -300 -40 ^ I -60 Z o ;¡ :r -80 j (1) ..... - -100 en' -120 £ ro -140 ~ II ..... -900 o^ -160 ;:I> I - Q) -1000 .æ - € -1100 o Z -150 -1200 -200 -1300 -250 -1400 -300 ~ -1500 Z o -350 ª -1600 j -400 ~ -1700 - -450 -1800 en¢:: (') 0 WI.C) -500 ~ II -1900 (') E 3;: II OJ -550 N ro -2000 CJ'1 0 ;:I>(f) 50 Slot: slot E IVE 0 Well: M-17 . .. Wellbore: M-17 v4ÄPR 2 9 2005 Seale 1 em Afä&.Gt/ (,fB'êt) ~ \. r .., ,... , -700 -600 -500 ~¡r-IR _'icWi3. ~i1\m¡¡.~n Am::harag -100 ¿"~ /; " ~ /Ø'~ /,>,~ ~? .:'¿ /,,;ß i:b -100 -200 -300 -400 -500 -600 -700 -800' -900 ^ I -1000 Z 0 ;:¡. :r -1100 -::;; (1) '(1) - - -1200 -1300 -1400 -1500 -1600 -1700 -1800 (f) (') D> ro -1900 ..... (') 3 II -2000 U\ 0 ;:I> -200 -400 ~ ."( ..f "" .f "" d' ~ " .# """.f "'-.,,"' / ~#' '-... .f. J " . ~I .J ~# ;\t / ~x# ! . X. "; .f~.f .' ~ / ..# ~\.,d' I ..~ '8001 'é~ / ~ d' 2900/.~ 2200 ;/ .é\ "d' \ \Ø,# \, ,\ 3000 ",,#'\ \.1 , \ \\ / d'\ \,# I q~ \ " I ' \ "7 )\,~ / <& 7 I I / =i ; -/ / ¡ J J 3500/ ! / 17'" -500 -600 -700 -800 / lJ -700 -600 -500 -400 -300 -200 -100 Seale 1 em = 50 fast (feet) -> . . ~, UNOCALe UNOCAL M-17 V4, M-17 V4 slot #A1-9, STEELHEAD Platform CLEARANCE LISTING Page 1 Date Printed: 28-Mar-2005 McArthur River Field, TBU, Cook Inlet, Alaska Ellipse separations are reported ONLY if BOTH wells have uncertainty data Only Depth and MaQnetic Reference Field error terms are correlated across tie p~ C· E··· I VE· D Proximities beyond ft with expansion rate of ft/1 OOOft are not reported- Cutoff is calculated on CENTRE to CENTRE distance APR 2 9 2005 Summary data uses Closest Approach clearance calculation for all minima Hole size/CasinQs ARE included Alaska Oil g Gas COO$ Commi$sÌ!:ìI"I Hole size/CasinQs are NOT subtracted from Centre-Centre distan~· .... -. ..... j( . ... . Ellipses scaled to 2,OOstandard deviations. Anchorage 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 M-15 M-15 slot #A1-8 STEELHEAD 4,33 65.62 65.62 0.85 459,32 1,55 480.00 Platform M-15 M-15 ST slot #A 1-8 STEELHEAD 4.33 65,62 4275.43 0,85 459.32 1.55 480.00 Platform M-13 M-13 slot #A1-1 STEELHEAD 4,40 507.94 507,94 0,24 480,00 1,13 480.00 Platform M-14 M-14Rd slot #A1-11 STEELHEAD 7.72 500,00 500.00 3.53 482,95 2.88 482.95 Platform M-14 M-14 slot #A1-11 STEELHEAD 7.72 500.00 500,00 3.53 482.95 2.88 482.95 Platform M-19 M-19 slot #A1-6 STEELHEAD 11,88 0,00 0.00 9.30 246,06 8,27 459.32 Platform M-12 M-12 slot #A1-3 STEELHEAD 12.08 350.00 350.00 7,20 442.91 3.71 475.72 Platform M-12 M-12 PB1 slot #A 1-3 STEELHEAD 12.08 350.00 350,00 6.92 459.32 3,40 459,32 Platform All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig (Planned Datum 160,3ft 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 (10) Casings Included Prepared by Baker Hughes Incorporated · REC~E'\lED · UNOCALe APR '2 (1 ZO~EARANCE LISTING Page 2 M-17 V4, M-17 V4 .' vCate Printed: 28-Mar-2005 slot #A1-9, STEELHEADÆ_tJj& Gm; 1M~~rt\1f#frßiMfM Field, TBU, Cook Inlet, An:~hor£ge Alaska UNOCAL M-16 M-16 slot #A1-4 STEELHEAD 13.68 135.00 300,00 8,66 459.32 3,96 480,00 Platform M-29 M-29 slot #81-7 STEELHEAD 98.11 524.93 524,93 93,55 480.00 30,38 738.19 Platform M-29 M-29 slot #81-7 STEELHEAD 98.11 524,93 524.93 93,55 480,00 30,38 738.19 Platform M-25 M-25 slot #81-11 STEELHEAD 98,24 558,71 558.71 93,85 558.71 30.24 574.15 Platform 81-6 81-6 slot #81-6 STEELHEAD 98,60 508,53 508.53 93.43 480.00 27.47 738.19 Platform 81-8 81-8 slot #81-8 STEELHEAD 102.72 349,25 500.00 98.06 480.00 29.41 738.19 Platform M-31 M-31St #2 slot #81-12 STEELHEAD 103.64 508,53 508.53 99.99 480.00 54.29 738,19 Platform M-31 M-31 slot #81-12 STEELHEAD 103.64 508,53 508.53 99.99 480.00 54.29 738,19 Platform M-31 M-31 St#1 slot #81-12 STEELHEAD 103.64 508.53 508,53 99.99 480.00 54.29 738.19 Platform M-30 M-30 slot #81-9 STEELHEAD 107.24 300.00 300,00 102,76 360,89 30,70 606.96 Platform M-32 M-32 St#1 slot #81-10 STEELHEAD 107.75 508.53 508,53 102.85 490.96 31.58 672.57 Platform M-32 M-32 St#4 slot #81-10 STEELHEAD 107.75 508.53 508,53 102.85 490,96 31,58 672.57 Platform M-32 M-32 St P81 slot #81-10 STEELHEAD 107.75 508.53 508,53 102.85 490.96 31.58 672.57 Platform M-32 M-32 St#3 slot #81-10 STEELHEAD 107,75 508,53 508.53 102.85 490,96 31,58 672.57 Platform M-32 M-32 St#2 slot#81-10 STEELHEAD 107,75 508,53 508.53 102,85 490.96 31.58 672.57 Platform M-32 M-32 slot #81-10 STEELHEAD 107.75 508,53 508.53 102,85 490.96 31.58 672,57 Platform M-27 M-27 slot #81-4 STEELHEAD 107.90 449.99 449,99 104.01 480,00 60,22 672.57 Platform M-28 M-28 slot #81-3 STEELHEAD 112.21 280,00 280,00 106.99 480,00 33.44 574.15 Platform M-26 M-26 slot #81-1 STEELHEAD 112,22 500.00 500,00 106.24 492,13 28.30 656.17 Platform 81-2 81-2 ST slot #81-2 STEELHEAD 113,33 325,00 325.00 108.75 360.89 36.97 508.53 Platform 81-2 81-2 slot #81-2 STEELHEAD 113.33 325,00 325.00 108.75 360.89 36.95 524.93 Platform M-7 M-7 slot #82-7 STEELHEAD 142.09 500.00 500.00 137.12 480.00 48.10 639.76 Platform M-5 M-5 slot #82-11 STEELHEAD 142.78 524.93 524.93 137,64 480.00 32,65 951,44 Platform M-3 M-3 slot #82-10 STEELHEAD 145.78 524.93 524.93 141,28 480.00 43.52 1164.70 Platform M-1 M-1 slot #82-8 STEELHEAD 145.96 347.24 347,24 141,16 442.91 37.22 700,00 Platform M-1 M-1 St#1 slot #82-8 STEELHEAD 145.96 347.24 347,24 141.16 442.91 37,22 700.00 Platform M-2 M-2 slot #82-3 STEELHEAD 147.70 0.00 500.00 142.97 480.00 20.59 2050.52 Platform All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig (Planned Datum 160,3ft 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) Casings Included Prepared by 8aker Hughes Incorporated UNOCALe RE, (~E~!VFn· UNOCAL . ..,J.ro ·C[,'ËÄRANCE LISTING Page 3 M-17 V4, M-17 V4 ,APR 2 9 20ðite Printed: 28-Mar-2005 slot #A1-9, STEELHEAD Platform McArthur Riyer Field, TBU, Cook Inlet, Alaska Oil &. Lmnm¡SSIOi).'aska . l~nC!;ûH,;;gt:¡ M-4 M-4(Drill slot #B2-9 STEELHEAD 152,39 300,00 300,00 148.05 480,00 50,94 721.78 Out Platform M-9 M-9 slot #B2-1 STEELHEAD 153.47 175,00 175.00 148.50 480,00 45.71 639.76 Platform RLF #1 RLF #2 slot #Relief STEELHEAD 420.94 1345.14 1345.14 407.88 1345,14 31.96 1459.97 Wells 1 &2 Platform All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Datum 160.3f1 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) Casings Included Prepared by Baker Hughes Incorporated . . URDCAL. UNOCAL CLEARANCE LISTING Page 4 M-17 V4, M-17 V4 REC;E:I\(~hi) Printed: 28-Mar-2005 slot #A1-9, STEELHEAD Platform <" ~cArtl1ur River Field, TBU, Cook Inlet, .~PR2 .~ t.OUJ Alaska scr ~, (~',.tt \":u¡mllIS I n ',,!'hf 0,00 0,00 O,OON O,OOE M-25 0,00 7,95 78.21 N 70,06E 41,9 105,30 102.97 16.40 16,40 O,OON O,OOE M-25 8,46 16,41 78.21 N 70,06E 41,9 105,00 102,46 100,00 100,00 O.OON O,OOE M-25 92,07 100,02 78.31 N 69,93E 41,8 104,99 102.04 200.00 200,00 O,OON O,OOE M-25 192.40 200,35 78.16N 70,OOE 41,9 104,92 101,36 300,00 300,00 O.OON O,OOE M-25 291.89 299,83 77.94N 70,23E 42,0 104,91 100.72 400,00 400,00 O.OON O,OOE M-25 392.19 400,13 77.47N 70,58E 42,3 104.80 99.97 480,00 480.00 O,OON O.OOE M-25 476.92 484,86 76.62N 70,10E 42,5 103,96 98.66 487,93 487.93 O,OON O,OOE M-25 480.00 487,93 76.51N 70,01 E 42,5 103,71 98.39 500,00 500,00 O,OON O.OOE M-25 503.12 510,97 75.08N 68,81 E 42,5 102,43 98.17 558,71 558.70 0.87S 0.61W M-25 555.00 562,62 71.32N 65,91 E -172.3 98,24 93.85 574,15 574.12 1.388 0.96W M-25 566.98 574,60 71.03N 65,78E -172.3 98,48 94.04 600.00 599.94 2.508 1.75W M-25 586,26 593.87 71.47N 66.05E -172.4 100,53 96.06 700.00 699.50 9.998 7.00W M-25 688,15 695.44 78.57N 69,21 E -174,2 116,91 112.26 750,00 749.03 15,618 10,93W M-25 738,69 745.95 79,83N 70,02E -174,6 125.18 120.41 800,00 798.33 22.588 15,43W M-25 785,95 793,19 80,57N 71.29E -170.8 134.86 129.94 900,00 896.12 40.968 25,24W M-25 890,99 898,17 82,33N 72.04E -167,3 157,06 152.04 1000,00 992.52 65.198 36,11W M-25 987,71 994.80 78,65N 70.76E -165,6 179.21 173.83 1100,00 1087.16 95.188 47.98W M-25 1081.08 1088,16 77,83N 70.33E -165.4 209.60 203.77 1200.00 1179,68 130.82S 60.83W M-25 1172,64 1179.72 77.54N 70,53E -165,7 246.31 239.98 1300,00 1269,76 171.98S 74.59W M-25 1262,39 1269,47 77.60N 70,63E -166,2 288.75 281.89 1400.00 1357,05 218.508 89.22W M-25 1349,25 1356,33 77.73N 70,45E -166,9 336.52 329.12 1500.00 1441,22 270.208 104,67W M-25 1434,99 1442,07 77.65N 70,59E -167.4 389,51 381.55 1600.00 1521,96 326.918 120,87W M-25 1515,49 1522,57 77.47N 70,54E -167,8 447.39 439,15 All data is in Feet unless otherwise stated Coordinates are from 810t and TVD's are from Rig (Planned Datum 160,3ft 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) Casings Included Prepared by Baker Hughes Incorporated . . UNOCAL. M-17 UV~~~~~ V4 RE CE ~\lE9~~i~~e~:L~~~~:~_;;og5e 5 slot #A1-9, STEELHEAD PlatfO~R :\~ 9M~~ur River F~~~:'k:BU, Cook Inlet, Alaska Oii &, 0,00 0.00 O,OON O.OOE M-27 0.08 0.08 78.32N 75,86E 44,1 109,04 106,70 100.00 100,00 O,OON O.OOE M-27 100,32 100.31 78.06N 75.92E 44,2 108,89 106,23 200.00 200,00 O,OON O.OOE M-27 200,36 200,36 77.63N 75,95E 44,4 108,60 105,61 300.00 300.00 O,OON O.OOE M-27 300,37 300.37 77.23N 75,89E 44,5 108,27 104,95 400.00 400.00 O,OON O.OOE M-27 400,16 400,16 76.61N 76,08E 44,8 107,97 104,31 449.99 449.99 O,OON O.OOE M-27 450,00 449,99 76.14N 76.45E 45,1 107,90 104,08 480.00 480.00 O,OON O.OOE M-27 479.95 479.94 75.77N 76,84E 45,4 107,91 104,01 500.00 500,00 O,OON O.OOE M-27 499,95 499.94 75.52N 77,10E 45,6 107,92 105,07 600.00 599.94 2,508 1.75W M-27 599,16 599.11 74.06N 79,23E -168.4 111 ,45 108,43 672.57 672.25 7,448 5.21W M-27 670,06 669,97 73.26N 81,38E -167.9 118,39 115,22 700.00 699,50 9,998 7.00W M-27 697,26 697,15 73.06N 82,29E -167.8 121,96 118.74 750.00 749,03 15.618 10,93W M-27 746,00 745.86 72.92N 84,02E -167.8 129,85 126,52 800.00 798,33 22,588 15.43W M-27 794,61 794.44 73,01 N 85,78E -164.1 139,27 135,82 900,00 896,12 40,968 25.24W M-27 891,00 890.76 73,62N 89.45E -160.2 162,21 158,82 1000.00 992,52 65,198 36,11W M-27 982,78 982.43 74,97N 93.70E -158.8 191.31 187,66 1100.00 1087,16 95,188 47.98W M-27 1069.93 1069.36 77,45N 99.20E -158,3 227,55 223,73 1200.00 1179,68 130.828 60.83W M-27 1155.45 1154.52 81,14N 106,14E -158.3 271,00 266,93 1300.00 1269,76 171.988 74.59W M-27 1233.60 1232.21 85,77N 113,28E -158.5 321,15 316,80 1400,00 1357,05 218.508 89.22W M-27 1308.96 1306.94 91,64N 120.95E -158,6 377.98 373,31 1500.00 1441,22 270,208 104,67W M-27 1383.46 1380.70 98,30N 129,08E -158,8 440,56 435,55 All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig (Planned Datum 160.3ft 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) Casings Included Prepared by Baker Hughes Incorporated . . UNOCAL. UNOCAL CLEARANCE LISTING Page 6 M-17 V4, M-17 ø 1= eEl \fE 0 Date Printed: 28-Mar-2005 slot #A1-9, STEELHEAb Þmtorm McArthur River Field, TBU, Cook Inlet, APR 2 '9 2005 Alaska "on r:: ,',~ '). CtìmmlSSI ~ 0.00 0.00 O,OON O.OOE M-28 0,10 0,10 83.09N 76,32E 42.6 112.82 110.47 100,00 100.00 O,OON O,OOE M-28 100.30 100,30 82.88N 76.33E 42.6 112.67 109.64 200.00 200.00 O,OON O,OOE M-28 200.34 200,34 82.42N 76.40E 42,8 112.38 108.76 280.00 280.00 O,OON O.OOE M-28 280.00 280,00 82.05N 76,55E 43,0 112.21 108.08 300.00 300.00 O,OON O.OOE M-28 299.99 299,98 81.98N 76,63E 43.1 112.22 107.97 400.00 400.00 O,OON O.OOE M-28 399.98 399,97 81.54N 77.16E 43,4 112.26 107.39 480.00 480,00 O,OON O.OOE M-28 479.79 479,78 81.05N 77.82E 43,8 112.37 106.99 500.00 500.00 O,OON O.OOE M-28 499.35 499,34 80.99N 78,06E 43,9 112.48 108.09 574.15 574.12 1,388 0.96W M-28 572.68 572.66 80.76N 79,18E -170.7 114.76 110.14 600,00 599.94 2,508 1.75W M-28 598.10 598,07 80.64N 79,76E -170,5 116.45 111.79 700.00 699.50 9.998 7.00W M-28 696.26 696,18 80.23N 82,97E -170,0 127.46 122.56 750.00 749.03 15.618 10.93W M-28 745.25 745,14 80.29N 84.78E -169,9 135.54 130.50 800.00 798.33 22.588 15.43W M-28 794.37 794,22 80.47N 86.59E -166,0 145.06 139.87 900.00 896.12 40.968 25,24W M-28 891.83 891,62 81.04N 89,89E -161,9 167.80 162.58 1000,00 992.52 65,198 36.11 W M-28 986.10 985,83 81.97N 92.97E -160,5 195.86 190.26 1100.00 1087.16 95,188 47,98W M-28 1076,74 1076,39 83,75N 96,72E -160,2 230.37 224.49 1200.00 1179.68 130,828 60,83W M-28 1163,93 1163,45 86,89N 99.95E -160,6 271.13 264.88 1300.00 1269.76 171,988 74,59W M-28 1247,38 1246,72 91,91 N 102,24E -161,6 318.48 311.85 1400.00 1357.05 218.508 89,22W M-28 1317,40 1316,44 98,14N 103,65E -162,3 372.96 365.95 1500,00 1441.22 270.208 104,67W M-28 1380,32 1378,82 106,26N 105,12E -162.9 435.46 428.07 1600.00 1521.96 326.918 120,87W M-28 1443,55 1441,24 116.18N 106,72E -163,5 504,61 497,10 All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Datum 160.3ft 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) Casings Included Prepared by Baker Hughes Incorporated . . UNOCALe UNOCAL CLEARANCE LISTING Page 7 M-17 V4, M-17 V4 C t: r·¡: ~ \ lr=. Ate Printed: 28-Mar-2005 slot #A1-9, STEELHEAD PlcltfMm Y,.¡,.,J .-" iNttÅnirúr River Field, TBU, Cook Inlet, APR ,:" q 2005 Alaska ,.. " ~, ç¡ ~ "r~ 0.00 0,00 O.OON O,OOE M-29 0.01 0.02 77,36N 63.77E 39.5 100.26 97,92 100,00 100,00 O,OON O,OOE M-29 100,08 100.08 77.42N 63.66E 39.4 100.23 97.26 200,00 200,00 O,OON O,OOE M-29 200,15 200.15 77.41N 63.51E 39.4 100.12 96.53 300,00 300,00 O,OON O,OOE M-29 300,29 300.29 77.1 ON 63.64E 39.5 99.97 95,74 400,00 400,00 O.OON O,OOE M-29 400,92 400,91 76.21 N 64.05E 40.0 99.56 94,69 480,00 480,00 O.OON O,OOE M-29 481.44 481,42 74,95N 64.15E 40.6 98.66 93.55 500,00 500,00 O.OON O,OOE M-29 501.77 501,75 74.59N 64.11 E 40.7 98.37 94,30 524,93 524.93 0.168 O,11W M-29 526.71 526,68 74,14N 63,95E -174,2 98.11 93,98 600.00 599.94 2.508 1.75W M-29 601.99 601,95 72.95N 63,15E -174,3 99.54 95,22 700,00 699.50 9.998 7,OOW M-29 701.69 701,63 71.66N 61,57E -174,9 106.64 101.97 738,19 737.35 14.178 9.92W M-29 739.63 739,56 71.19N 60,94E -175,3 110.96 106.13 750.00 749.03 15.618 10,93W M-29 751,34 751.27 71.05N 60,75E -175,4 112,48 107.60 800.00 798.33 22.588 15,43W M-29 800.73 800.65 70.44N 59,94E -171,9 119,74 114.66 900.00 896.12 40,968 25,24W M-29 898,79 898,69 69.20N 58,51E -168.4 138,41 133.17 1000,00 992.52 65.19S 36,11W M-29 996.61 996.49 67.58N 57,29E -167.2 162,38 156.73 1100,00 1087.16 95.188 47,98W M-29 1095,72 1095.54 64.86N 55,34E -167,2 190,67 184.96 1200,00 1179.68 130,828 60,83W M-29 1186,11 1185.86 62.23N 53,29E -167.6 224,34 218.48 1300,00 1269.76 171,988 74,59W M-29 1276,14 1275,85 60.21N 51,74E -168,2 264,40 258.30 1400,00 1357.05 218,508 89,22W M-29 1361,85 1361.55 58.91N 50,68E -168.8 310,71 304.40 1500,00 1441.22 270,208 104.67W M-29 1446.32 1446.01 57.82N 50,26E -169.2 362,80 356,24 1600,00 1521.96 326,918 120.87W M-29 1528.29 1527.97 56.83N 49,68E -169.6 419,97 413.40 1700,00 1598.97 388,398 137.76W M-29 1605.90 1605.57 55.98N 48,92E -169.9 482,04 475,16 All data is in Feet unless otherwise stated Coordinates are from 810t and TVD's are from Rig ( Planned Datum 160.3ft 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) Casings Included Prepared by Baker Hughes Incorporated . . UNOCALe UNOCAL CLEARANCE LISTING Page 8 M-17 V4, M-17 V4 Date Printed: 28-Mar-2005 slot #A 1-9, STEELHEAD PIRE't; E: I ~'Ëtr River F~~~:'k:BU, Cook Inlet, APR 2 9 2005 0.00 0,00 O,OON O,OOE M-29 0.01 0.02 77.36N 63.77E 39.5 100.26 97.92 100,00 100.00 O,OON O,OOE M-29 100.08 100,08 77.42N 63.66E 39.4 100.23 97.26 200,00 200,00 O,OON O,OOE M-29 200.15 200,15 77.41 N 63.51E 39.4 100.12 96,53 300,00 300.00 O,OON O,OOE M-29 300.29 300,29 77.10N 63,64E 39.5 99.97 95,74 400,00 400.00 O,OON O,OOE M-29 400.92 400,91 76.21 N 64,05E 40.0 99.56 94.69 480,00 480.00 O,OON O,OOE M-29 481.44 481,42 74,95N 64,15E 40.6 98.66 93,55 500,00 500.00 O,OON O,OOE M-29 501.77 501,75 74.59N 64,11 E 40.7 98.37 94,30 524,93 524.93 0.168 0.11W M-29 526.71 526,68 74.14N 63.95E -174,2 98.11 93,98 600,00 599.94 2.508 1.75W M-29 601.99 601 ,95 72.95N 63,15E -174.3 99.54 95,22 700,00 699,50 9.998 7,OOW M-29 701.69 701,63 71.66N 61,57E -174.9 106.64 101.97 738,19 737.35 14.178 9.92W M-29 739.63 739,56 71.19N 60,94E -175,3 110,96 106.13 750.00 749.03 15.618 10,93W M-29 751.34 751,27 71.05N 60,75E -175.4 112.48 107.60 800.00 798.33 22,588 15,43W M-29 800.73 800,65 70.44N 59,94E -171,9 119.74 114.66 900,00 896.12 40.968 25,24W M-29 898.79 898,69 69.20N 58,51E -168.4 138.41 133.17 1000.00 992.52 65.198 36,11W M-29 996.08 995,96 67.61N 57,38E -167.1 162.44 156.71 1100.00 1087.16 95,188 47,98W M-29 1094,28 1094,11 65.04N 55,91 E -167.0 191.08 184.95 1200.00 1179.68 130,828 60,83W M-29 1189,12 1188,88 61.80N 53,93E -167.5 224,40 217.81 1300,00 1269.76 171,988 74,59W M-29 1280,17 1279,86 58,75N 51,94E -168.1 263.34 256.28 1400.00 1357.05 218,508 89,22W M-29 1366,65 1366,28 56.33N 50,10E -168,8 308.26 300.72 1500.00 1441.22 270,208 104,67W M-29 1450,00 1449,60 54,67N 48,40E -169,4 359.22 351.22 1600.00 1521,96 326.918 120.87W M-29 1528,67 1528,25 53.78N 46.96E -169,8 416.08 407.90 1700.00 1598.97 388.398 137.76W M-29 1603,75 1603,32 53.29N 45.68E -170,2 478.28 469.64 All data is in Feet unless otherwise stated Coordinates are from 810t and TVD's are from Rig (Planned Datum 160,3ft 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) Casings Included Prepared by Baker Hughes Incorporated \ . . UNOCAL8 UNOCAL M-17 V4, M-17 V4 slot #A1-9, STEELHEAD Platform CLEARANCE LISTING Page 9 Date Printed: 28-Mar-2005 McArthur River Field, TBU, Cook Inlet, Alaska 0,00 0.00 O,OON O.OOE M-30 0,00 0,00 86.15N 64,46E 36.8 107.60 105.26 16,40 16.40 O,OON O.OOE M-30 16,36 16,36 86.15N 64.47E 36.8 107.60 105.01 100.00 100,00 O,OON O.OOE M-30 99,87 99,87 86.14N 64,61E 36,9 107.67 104.71 200.00 200,00 O,OON O.OOE M-30 200.38 200,38 85.91 N 64,72E 37.0 107.56 103.96 300.00 300.00 O,OON O.OOE M-30 300,00 300,00 85.49N 64,75E 37,1 107.24 103.01 360.89 360,89 O,OON O.OOE M-30 360,32 360,31 85.48N 65,02E 37.3 107.40 102.76 400.00 400.00 O,OON O.OOE M-30 398.87 398,86 85.69N 65,36E 37.3 107.78 102.92 480.00 480,00 O,OON O.OOE M-30 478,28 478,26 86.50N 66,21E 37,4 108,95 103.58 500.00 500.00 O,OON O.OOE M-30 498,27 498.26 86.75N 66,42E 37,4 109,27 104.89 600.00 599,94 2,508 1.75W M-30 598,60 598.57 88.09N 66,92E -177.8 113,69 108.80 606,96 606,88 2,868 2.00W M-30 605,80 605,78 88.20N 66,90E -177.9 114.20 109.29 700,00 699,50 9,998 7.00W M-30 698,67 698.62 89.92N 65,87E -178.9 123.67 118.57 750.00 749,03 15.61S 10,93W M-30 748,35 748.27 91.08N 64,74E -179.7 130.80 125.59 800.00 798,33 22.588 15.43W M-30 797,83 797.72 92.28N 63,38E -176.5 139,30 133.97 900,00 896,12 40.968 25,24W M-30 895,33 895.15 94.66N 60.65E -173.3 160.53 155.26 1000.00 992,52 65,198 36.11W M-30 991 ,42 991,19 96.78N 58,42E -172.1 187.53 181.99 1100.00 1087,16 95.188 47.98W M-30 1082.76 1082.47 99.44N 56,17E -171.9 220.79 215.05 1200.00 1179,68 130.828 60.83W M-30 1167.02 1166.57 103.79N 53,59E -172.3 261,35 255.34 1300.00 1269,76 171.988 74,59W M-30 1249.16 1248.42 110.15N 51.20E -172.9 309,64 303.29 1400.00 1357,05 218.508 89.22W M-30 1325.00 1323.89 117.42N 49.41 E -173.3 364.90 358.18 1500.00 1441.22 270.208 104,67W M-30 1390.74 1389.13 125.47N 48,49E -173.5 427,47 420.35 1600.00 1521,96 326.918 120,87W M-30 1454,23 1451.94 134.68N 48.04E -173.7 496,48 489.21 All data is in Feet unless otherwise stated Coordinates are from 810t and TVD's are from Rig ( Planned Datum 160.3ft 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) Casings Included Prepared by Baker Hughes Incorporated . . UNOCALe UNOCAL REC6i.\lliiLÌcE LISTING Page 10 M-17 V4, M-17 V4 î\PR 'J,Q ~rinted: 28-Mar-2005 slot #A1-9, STEELHEAD Platform J M~l'fh~rR1ver Field, TBU, Cook Inlet, Alaska Chi & Cl!m¡n¡stt~ka IUlchar1::ge 0.00 0.00 O.OON O,OOE M-15 0,00 0,00 1.728 3.97E 113.4 4.33 1.99 65.62 65.62 O.OON O,OOE M-15 65,62 65,62 1.818 3.93E 114,7 4.33 1.72 100.00 100.00 O.OON O.OOE M-15 100.00 100,00 1,908 3,89E 116,1 4.33 1.66 200.00 200.00 O.OON O.OOE M-15 200.00 200,00 2,158 3.79E 119.6 4.36 1.36 300.00 300.00 O,OON O.OOE M-15 300,00 300,00 2,318 3,79E 121.3 4.44 1.11 400.00 400.00 O,OON O.OOE M-15 400,00 399.99 2.518 3,81E 123.3 4,56 0.91 459.32 459,32 O.OON O.OOE M-15 459,30 459.30 2.87S 3.73E 127.5 4,70 0,85 480.00 480,00 O.OON O,OOE M-15 479,98 479.98 3.098 3.66E 130.2 4,79 0,87 500,00 500.00 O.OON O,OOE M-15 499.98 499.98 3.318 3.60E 132,6 4.89 2.01 600,00 599.94 2.50S 1.75W M-15 599.95 599,90 5.858 2.36E -85,8 5.30 2.26 700,00 699.50 9.998 7,OOW M-15 699.89 699,69 10,658 0.47W -119,2 6.57 3,34 750.00 749.03 15.618 10,93W M-15 749.86 749,50 14,008 2.42W -135,7 8.67 5.33 800.00 798.33 22.58S 15.43W M-15 799.77 799,20 17,978 4.59W -144,1 11.81 8.33 900.00 896.12 40.968 25,24W M-15 899.41 898,27 27,428 9.42W -156.4 20.94 17.50 1000,00 992.52 65.198 36,11W M-15 999.56 997,52 39.568 15,16W -163.5 33.47 29,83 1100,00 1087.16 95.188 47,98W M-15 1100.96 1097.15 56.90S 22,31W -167.0 47.16 43,36 1200.00 1179.68 130.828 60.83W M-15 1202.62 1195.80 80.148 29,95W -168.1 61,49 57.38 1300.00 1269,76 171.988 74.59W M-15 1305.13 1293.64 109.54S 38,10W -168.1 76,16 71.60 1400.00 1357,05 218.508 89.22W M-15 1409,67 1391.27 145.758 47.20W -167.9 90,72 85.59 1500.00 1441.22 270.208 104,67W M-15 1449,00 1427,39 160.848 51.05W -167,1 122.58 117 .20 1600.00 1521.96 326.918 120,87W M-15 1449,00 1427,39 160,848 51.05W -164,9 203.46 198.12 1700,00 1598.97 388,398 137.76W M-15 1449,00 1427,39 160,848 51,05W -160,4 297.89 292.36 1800,00 1671.96 454,448 155,29W M-15 1449,00 1427,39 160,848 51,05W -150.7 396.08 390.36 1900,00 1740,66 524,798 173,39W M-15 1449.00 1427.39 160.848 51,05W -125.0 495,55 489.64 All data is in Feet unless otherwise stated Coordinates are from 810t and TVO's are from Rig ( Planned Oatum 160.3ft 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) Casings Included Prepared by Baker Hughes Incorporated . . UNOCAL. UNOCAL CLEARANCE LISTING Page 11 slot #A 1 ~;,1~T~~~~~:~42~C E I\'~~~t~i:~~~~:;d~~:~~-~~~~ Inlet, APR '2 9 ~:005 Alaska , síOI) , t)¡nrm~. 0,00 0.00 O,OON O.OOE M-15 0,00 0,00 1,728 3,97E 113,4 4.33 1.99 65,62 65.62 O,OON O.OOE M-15 65,62 65,62 1,818 3,93E 114,7 4.33 1.72 100.00 100.00 O,OON O.OOE M-15 100.00 100,00 1,908 3,89E 116,1 4.33 1.66 200,00 200.00 O.OON O,OOE M-15 200.00 200,00 2,158 3.79E 119,6 4.36 1.36 300,00 300.00 O.OON O,OOE M-15 300,00 300,00 2.318 3.79E 121.3 4.44 1.11 400,00 400.00 O.OON O,OOE M-15 400,00 399.99 2.518 3.81E 123.3 4,56 0.91 459,32 459,32 O,OON O,OOE M-15 459,30 459.30 2.87S 3,73E 127.5 4,70 0,85 480.00 480,00 O,OON O.OOE M-15 479,98 479.98 3,098 3,66E 130.2 4.79 0.87 500.00 500.00 O,OON O.OOE M-15 499,98 499.98 3,318 3,60E 132.6 4.89 2.01 600.00 599.94 2,508 1.75W M-15 599.95 599,90 5,858 2.36E -85,8 5.30 2.26 700.00 699.50 9.998 7,OOW M-15 699,89 699,69 10,658 0.47W -119,2 6,57 3.34 750.00 749.03 15,618 10,93W M-15 749,86 749.50 14.008 2.42W -135.7 8,67 5.33 800,00 798,33 22,588 15.43W M-15 799,77 799.20 17.978 4,59W -144.1 11,81 8,33 900,00 896,12 40,968 25.24W M-15 899,41 898.27 27.428 9,42W -156.4 20,94 17.50 1000.00 992,52 65.198 36,11W M-15 998,70 996,83 38,398 14,63W -164,0 34.61 30.89 1100,00 1087,16 95.188 47,98W M-15 1098,28 1095,31 51,768 20.60W -168,3 51.97 48,08 1200,00 1179.68 130,828 60,83W M-15 1198,33 1193,68 68.368 28.10W -171.4 71,89 67.79 1300.00 1269.76 171,988 74.59W M-15 1297,56 1290,65 87.21S 37.50W -174,3 94,85 90.52 1400.00 1357.05 218.50S 89.22W M-15 1395,01 1385.47 106.928 48,31W -176.8 122,19 117,61 1500.00 1441.22 270.208 104,67W M-15 1489.65 1477.37 126.408 59,77W -178.9 154.93 150.06 1600.00 1521,96 326,918 120,87W M-15 1587.73 1572.19 147,828 72,79W 179,3 192.11 187.19 1700,00 1598,97 388,398 137,76W M-15 1687,37 1667,55 172,948 87.00W 178,1 231.73 226.45 1800,00 1671.96 454,448 155.29W M-15 1786,87 1761,85 201,818 100.14W 177,6 273.76 268.12 1900,00 1740.66 524.798 173,39W M-15 1889,02 1857,54 235,728 111.21W 177.8 317,94 311.94 2000.00 1804.82 599.198 191,98W M-15 1996,52 1956,29 276,758 122.10W 178,3 363,03 356,70 2046.79 1833,21 635.318 200,83W M-15 2053,89 2007,90 300.948 128,63W 178.5 384,11 377.59 2100.00 1864,89 676.858 210,95W M-15 2113.03 2060.22 327.488 136,10W 178.5 407,21 400.49 2200.00 1924,43 754.918 229,97W M-15 2235.30 2165.22 387,318 154,48W 178,1 445,88 438.75 2300.00 1983,96 832.97S 248,98W M-15 2360.82 2268.38 455.12S 177.00W 177.6 478.38 470.79 2400.00 2043,50 911,048 268,OOW M-15 2487,63 2367.53 530,008 202,24W 176,9 504.49 496.40 3200.00 2558,26 1502,128 414.42W M-15 3388.68 2953.07 1182,108 403,98W 171,7 508.33 495.38 3300,00 2637.71 1560,788 430.03W M-15 3485,68 3012,91 1255,218 425,97W 170,7 483.90 470.17 3375,43 2700.00 1601,808 441.21W M-15 3557,65 3057,28 1309,518 442.19W 169,7 461,61 447.24 3475,43 2785.03 1652,538 455,18W M-15 3651,51 3115,16 1380.328 463.28W 168.4 427.96 412.63 3575.43 2872,27 1699.638 468,16W M-15 3744,00 3172,18 1450.138 484.00W 166.9 390.44 373,97 3675.43 2961.56 1743.028 480,11W M-15 3834.58 3227.97 1518.568 504,25W 164.8 349,19 331,31 3775.43 3052,73 1782.628 491,01W M-15 3922.40 3282.20 1584.818 523,84W 161.9 304,73 284,97 3875.43 3145,60 1818.348 500.86W M-15 4009.62 3336.03 1650.618 543,32W 157,6 257.29 234.86 3975.43 3240,01 1850,128 509.61W M-15 4094.50 3387,98 1714,848 562,78W 150,8 207.42 180.76 4075,43 3335.76 1877. 908 517.26W M-15 4175,89 3437,38 1776,618 581,97W 139,6 157.40 123.43 4175,43 3432.67 1901,638 523.80W M-15 4254,09 3484,83 1835,978 600.45W 120,4 113,61 67,35 4275,43 3530.57 1921,278 529.21W M-15 4329,91 3530,98 1893,438 618.23W 92.0 93.28 36.27 4375,43 3629.26 1936,768 533,47W M-15 4402,64 3575,12 1948,678 635.27W 64,3 115.92 67.63 4475.43 3728.56 1948.098 536,60W M-15 4473,89 3618,61 2002,598 651.92W 46.0 168.40 132.09 4575.43 3828,28 1955.248 538,56W M-15 4541.42 3660.30 2053.368 667.62W 35.6 233,45 204,11 4675.43 3928,22 1958.188 539,37W M-15 4603.08 3698.18 2099.848 681,95W 29,5 305,48 280.03 4695.43 3948,22 1958,268 539.40W M-15 4615.37 3705,69 2109.13S 684,84W -136.1 320.52 295.62 4700,00 3952,79 1958,268 539.40W M-15 4618,17 3707,40 2111,248 685,50W -136,3 323.99 4800.00 4052.79 1958,268 539.40W M-15 4677.48 3743,58 2156.098 699.60W -141,0 400.52 4900.00 4152.79 1958.268 539,40W M-15 4737,50 3780.06 2201.478 714.15W -144.3 478,14 All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Datum 160.3ft 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) Casings Included Prepared by Ba~er Hughes Incorporated . . UNOCALe M-17 UV~~~~~ V4 R EC E 1\~n;{~~n~:d~I:~~;~~~: 12 slot #A1-9, STEELHEAD Platform" R :D/lcArttwr River Field, TBU, Cook Inlet, r\P :,(., 9 ZUU:J Alaska All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig (Planned Datum 160.3ft 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) Casings Included Prepared by Baker Hughes Incorporated . . UNOCALe UNOCAL M-17 V4, M-17 V4 slot #A1-9, STEELHEAD Platform RE~IpA~~~r~STING Page 13 .'- \..!)~ Pfihtetl;t'28-Mar-2005 M~W ij-i'1'1~j~ield, TBU, Cook Inlet, ,¡í~-k,,·· 'Alaska Alaskíì O¡¡ & 0.00 0.00 O,OON O.OOE M-31 0,04 0,04 82.44N 66,57E 38,9 105.96 103.63 100,00 100.00 O.OON O,OOE M-31 100.05 100,05 82.28N 66.66E 39,0 105.89 103,23 200,00 200.00 O.OON O,OOE M-31 199,86 199,86 82,20N 66.82E 39.1 105,93 102,94 300,00 300,00 O.OON O,OOE M-31 300,76 300,76 81,98N 66.86E 39.2 105.79 102.47 400,00 400,00 O.OON O,OOE M-31 401,33 401.32 80,86N 66,73E 39,5 104,85 101,19 480,00 480,00 O,OON O,OOE M-31 481,09 481.07 79,60N 66,78E 40,0 103,91 99.99 500.00 500,00 O,OON O,OOE M-31 501,03 501.01 79,29N 66.83E 40,1 103,71 100.83 508.53 508,53 0,028 0.01W M-31 509,56 509.54 79,17N 66,85E -174.8 103.64 100.75 600.00 599.94 2,508 1.75W M-31 601,35 601.32 77.98N 66,77E -174.6 105.71 102.63 700.00 699.50 9,998 7,OOW M-31 701.75 701,71 76.90N 65,75E -175,0 113.35 110.07 738.19 737.35 14.17S 9.92W M-31 740.06 740,01 76.58N 64,93E -175,4 117.67 114.30 750.00 749.03 15.618 10,93W M-31 751.77 751,71 76.53N 64.59E -175,6 119.16 115.76 800,00 798.33 22,588 15.43W M-31 801.90 801,81 76.44N 62,73E -172,6 126.20 122.69 900,00 896.12 40.968 25,24W M-31 900.28 900,06 76,76N 57.81E -170,5 144.12 140.67 1000,00 992.52 65,198 36.11W M-31 996.79 996,41 77.51N 52.25E -170,7 167.88 164,18 1100.00 1087.16 95,188 47.98W M-31 1089,15 1088.60 79,08N 46.86E -171,6 198.40 194,55 1200.00 1179,68 130.828 60.83W M-31 1176.72 1176,02 81,73N 42.41 E -172.5 236.32 232,29 1300.00 1269,76 171,988 74.59W M-31 1261.68 1260.83 85,41 N 39,33E -173.2 281,61 277,36 1400.00 1357,05 218,508 89,22W M-31 1342.85 1341.86 89.87N 37,54E -173.6 333,75 329.26 1500,00 1441.22 270,20S 104.67W M-31 1420,14 1419.00 94.53N 36,49E -173.8 391 ,73 386.99 1600,00 1521.96 326,918 120.87W M-31 1488,32 1487,00 99.59N 36,20E -173,8 455.84 451.11 All data is in Feet unless otherwise stated Coordinates are from 810t and TVO's are from Rig (Planned Oatum 160,3ft 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) Casings Included Prepared by Baker Hughes Incorporated . . UNOCAL. UNOCAL CLEARANCE LISTING Page 14 M-17 V4, M-17 V4 RE C' ~~éitëPrlnted: 28-Mar-2005 slot #A1-9, STEELHEAD Platform ,.,,,",,, McArthur River Field, TBU, Cook Inlet, APFl 2, ;~ ¿ Alaska 0,00 0,00 O,OON O,OOE M-31 0,04 0,04 82.44N 66,57E 38,9 105,96 103.63 100,00 100.00 O.OON O,OOE M-31 100.05 100,05 82.28N 66.66E 39,0 105.89 103.23 200,00 200,00 O.OON O,OOE M-31 199.86 199,86 82,20N 66.82E 39.1 105.93 102.94 300.00 300,00 O,OON O,OOE M-31 300,76 300,76 81,98N 66,86E 39,2 105,79 102.47 400,00 400,00 O,OON O,OOE M-31 401,33 401,32 80.86N 66,73E 39,5 104,85 101 ,19 480.00 480.00 O,OON O,OOE M-31 481.09 481,07 79.60N 66,78E 40.0 103.91 99,99 500.00 500.00 O.OON O,OOE M-31 501,03 501,01 79.29N 66,83E 40,1 103.71 100,83 508,53 508,53 0.025 O,01W M-31 509,56 509.54 79,17N 66,85E -174,8 103.64 100,75 600.00 599,94 2.505 1,75W M-31 601,35 601,32 77,98N 66.77E -174,6 105,71 102,63 700.00 699.50 9,995 7.00W M-31 701,75 701,71 76,90N 65,75E -175.0 113,35 110.07 738.19 737,35 14.175 9.92W M-31 740,06 740.01 76.58N 64,93E -175.4 117.67 114,30 750,00 749,03 15,615 10,93W M-31 751.77 751,71 76,53N 64,59E -175,6 119.16 115.76 800,00 798.33 22,585 15.43W M-31 801.90 801,81 76.44N 62.73E -172.6 126,20 122.69 900,00 896,12 40,965 25.24W M-31 900,28 900,06 76,76N 57.81E -170,5 144.12 140,67 1000.00 992,52 65,195 36,11W M-31 996,79 996.41 77,51N 52.25E -170.7 167,88 164,18 1100,00 1087,16 95,185 47,98W M-31 1089.15 1088.60 79,08N 46,86E -171.6 198,40 194.55 1200,00 1179,68 130,825 60,83W M-31 1176,72 1176.02 81,73N 42,41E -172.5 236.32 232,29 1300.00 1269.76 171,985 74,59W M-31 1261,68 1260,83 85.41 N 39,33E -173,2 281,61 277.36 1400.00 1357.05 218,505 89,22W M-31 1342.85 1341,86 89,87N 37.54E -173,6 333,75 329.26 1500.00 1441,22 270,205 104,67W M-31 1420.14 1419.00 94,53N 36.49E -173.8 391,73 386,99 1600,00 1521,96 326,91S 120,87W M-31 1488,32 1487,00 99.59N 36.20E -173,8 455,84 451,11 All data is in Feet unless otherwise stated Coordinates are from 510t and TVO's are from Rig ( Planned Oatum 160.3ft 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) Casings Included Prepared by Baker Hughes Incorporated . . UNOCAL. UNOCAL M-17 V4, M-17 V4 slot #A1-9, STEELHEAD Platform CLEARANCE LISTING Page 15 Date Printed: 28-Mar-2005 McArthur River Field, TBU, Cook Inlet, Alaska 0.00 0,00 O.OON O,OOE M-31 0.04 0.04 82,44N 66.57E 38,9 105,96 103.63 100,00 100,00 O.OON O,OOE M-31 100,05 100.05 82,28N 66.66E 39,0 105,89 103,23 200,00 200,00 O,OON O.OOE M-31 199,86 199.86 82,20N 66,82E 39,1 105,93 102.94 300,00 300,00 O,OON O.OOE M-31 300,76 300,76 81.98N 66,86E 39,2 105.79 102.47 400,00 400.00 O,OON O.OOE M-31 401.33 401,32 80.86N 66.73E 39.5 104.85 101.19 480,00 480.00 O.OON O.OOE M-31 481,09 481,07 79.60N 66.78E 40.0 103.91 99.99 500.00 500.00 O.OON O,OOE M-31 501.03 501,01 79,29N 66.83E 40.1 103,71 100,83 508.53 508,53 0.02S O,01W M-31 509,56 509.54 79,17N 66.85E -174.8 103,64 100,75 600,00 599,94 2,50S 1.75W M-31 601,35 601.32 77,98N 66,77E -174.6 105,71 102.63 700.00 699,50 9,99S 7,OOW M-31 701,75 701.71 76.90N 65,75E -175.0 113.35 110.07 738.19 737,35 14.17S 9.92W M-31 740,06 740,01 76.58N 64,93E -175.4 117.67 114.30 750.00 749,03 15.61 S 10,93W M-31 751.77 751,71 76.53N 64.59E -175,6 119.16 115.76 800.00 798.33 22.58S 15.43W M-31 801,90 801,81 76.44N 62.7::!E -172,6 126.20 122.69 900.00 896.12 40,96S 25.24W M-31 900.28 900,06 76,76N 57.81E -170,5 144.12 140.67 1000,00 992.52 65,19S 36.11W M-31 996,79 996.41 77,51N 52.25E -170.7 167,88 164,18 1100.00 1087.16 95,18S 47.98W M-31 1089.15 1088.60 79,08N 46,86E -171.6 198,40 194,55 1200.00 1179,68 130.82S 60,83W M-31 1176.72 1176.02 81.73N 42,41 E -172.5 236.32 232.29 1300.00 1269,76 171,98S 74,59W M-31 1261.68 1260.83 85.41 N 39,33E -173.2 281.61 277.36 1400.00 1357.05 218,50S 89,22W M-31 1342,85 1341,86 89.87N 37,54E -173.6 333.75 329.26 1500.00 1441.22 270,20S 104.67W M-31 1420,14 1419,00 94.53N 36,49E -173,8 391.73 386.99 1600,00 1521.96 326.91 S 120.87W M-31 1488,32 1487,00 99,59N 36.20E -173,8 455.84 451.11 RECE\\/ED APR 2 9 2005 A\aska ai\ &. Gas Con:;· c~mmi~s¡O¡; .' Anchorage All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Datum 160.3ft 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) Casings Included Prepared by Baker Hughes Incorporated . . UNOCALe UNOCAL M-17 V4, M-17 V4 slot #A 1-9, STEELHEAD Platform CLEARANCE LISTING Page 16 Date Printed: 28-Mar-2005 McArthur River Field, TBU, Cook Inlet, Alaska 0.00 0,00 O.OON O,OOE M-2 2.65 -0.10 9.64N 147,38E 86,3 147,70 145,29 100,00 100,00 O,OON O,OOE M-2 102,21 99.45 9.51N 147.53E 86.3 147.84 144.86 200.00 200.00 O,OON O.OOE M-2 201.95 199,19 9,32N 148.02E 86.4 148.31 144.70 300,00 300.00 O.OON O,OOE M-2 302,64 299.89 9.61N 148.40E 86,3 148,71 144,47 400,00 400,00 O,OON O,OOE M-2 403,21 400.46 9,93N 148.36E 86,2 148.69 143.81 480,00 480.00 O,OON O.OOE M-2 483.61 480,85 9,74N 148,04E 86.2 148.36 142.97 500,00 500,00 O.OON O,OOE M-2 503.69 500,94 9.65N 147,93E 86,3 148,24 143,84 600,00 599,94 2.505 1,75W M-2 603,38 600,62 9,03N 147.41 E -129,4 149.61 144.71 700.00 699.50 9,995 7.00W M-2 703.10 700,33 8,26N 147.02E -131,6 155.10 149.69 750,00 749.03 15,615 10.93W M-2 752,78 750,01 7.43N 146,84E -133,0 159.45 153,95 800,00 798,33 22,585 15.43W M-2 802,35 799.56 5.94N 146.74E -130.6 164,66 159.05 900.00 896.12 40.965 25,24W M-2 900,19 897,22 O,13N 147.18E -128,6 177.25 171.72 1000,00 992.52 65,195 36.11 W M-2 995.63 992,08 9.925 149.70E -128,0 193.85 188.04 1100.00 1087,16 95,185 47.98W M-2 1098.50 1093.25 27.775 154.05E -127.7 213,07 206.90 1200.00 1179.68 130,825 60,83W M-2 1193,04 1184,71 50,985 159,63E -126.9 234.52 227.65 1300.00 1269.76 171,985 74.59W M-2 1290,81 1277.20 81.315 168,45E -125,8 259,50 251,54 1400.00 1357,05 218,505 89.22W M-2 1382.97 1361.80 116.14S 179.41E -124.1 287,51 278.10 1500,00 1441.22 270,205 104.67W M-2 1480,55 1448,80 157,955 193,56E -122,5 318.75 307.48 1600.00 1521,96 326.915 120,87W M-2 1577.55 1532.33 204.825 208,73E -120.8 351,63 338,42 1700.00 1598.97 388,395 137.76W M-2 1673.46 1611,79 256,025 224,90E -119.1 386.28 370.56 1800,00 1671.96 454.445 155.29W M-2 1769,46 1688,33 311.395 241,96E -117.4 422,54 404.03 1900.00 1740,66 524.795 173,39W M-2 1861.24 1758.98 367.385 259.17E -116.0 460,67 439.24 2000,00 1804.82 599,195 191.98W M-2 1953,28 1828,41 424,985 277.39E -114,9 501.21 476.74 2046.79 1833.21 635.315 200,83W M-2 1995,64 1860,16 451.765 285,73E -114,6 520.74 494,86 2050.52 1835,43 638,235 201,54W M-2 1999.02 1862.69 453,895 286.40E -114.6 522,31 496.33 RECEIVED APR 2 9 2005 Alaska Oil & Gas CCHut Anchorag{j All data is in Feet unless otherwise stated Coordinates are from 510t and TVD's are from Rig (Planned Datum 160.3ft 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 (10) Casings Included Prepared by Baker Hughes Incorporated . . UNOCALe UNOCAL M-17 V4, M-17 V4 slot #A 1-9, STEELHEAD Platform CLEARANCE LISTING Page 17 Date Printed: 28-Mar-2005 McArthur River Field, TBU, Cook Inlet, Alaska 0.00 0,00 O.OON O,OOE M-3 0,00 0.00 13,59N 147,03E 84,7 147,66 145,32 16.40 16,40 O.OON O.OOE M-3 16,39 16.39 13.58N 147.03E 84,7 147.66 145.07 100.00 100.00 O,OON O.OOE M-3 99,95 99,95 13.40N 147,07E 84.8 147.68 144.71 200,00 200,00 O.OON O,OOE M-3 200,08 200,08 13,05N 147,13E 84,9 147,70 144,10 300,00 300,00 O,OON O.OOE M-3 300,57 300,57 12.61N 147.04E 85,1 147.58 143.35 400.00 400.00 O,OON O.OOE M-3 401.58 401,57 11,36N 146.46E 85.6 146.91 142,37 480,00 480.00 O.OON O,OOE M-3 481,50 481.47 9.70N 145,75E 86,2 146,08 141,28 500,00 500,00 O.OON O.OOE M-3 501,31 501,27 9,26N 145.58E 86,4 145.88 142.12 524.93 524.93 0,168 0.11W M-3 526.24 526,19 8,67N 145.40E -128,5 145.78 141.97 600,00 599,94 2.508 1,75W M-3 600,81 600.74 6.89N 144,97E -128.6 147,03 143,08 700.00 699,50 9,998 7.00W M-3 700,60 700,50 4,45N 144,59E -130,3 152.28 148.10 750.00 749.03 15,618 10,93W M-3 750.26 750,15 3.25N 144,38E -131,6 156.45 152.15 800,00 798,33 22.588 15.43W M-3 799,74 799.61 2.05N 144.17E -129,4 161.49 157.04 900.00 896.12 40.968 25,24W M-3 898.19 898,04 0,048 143.59E -128,8 173.73 169.22 1000,00 992.52 65,198 36.11W M-3 994.29 994.12 1.59S 143,11E -131.1 190,17 185,06 1100.00 1087,16 95.188 47.98W M-3 1088.79 1088.61 2,668 142,84E -134.7 212.07 206.38 1164,70 1147.28 117,608 56,19W M-3 1148,93 1148,75 3,138 142.66E -137,3 229.44 223.28 1200,00 1179.68 130,828 60.83W M-3 1181,20 1181,02 3.318 142,56E -138.7 240,05 233,66 1300.00 1269,76 171.988 74.59W M-3 1271.18 1271.01 3,678 142.26E -142.6 274.50 267.39 1400.00 1357.05 218,508 89,22W M-3 1358,62 1358,44 3,858 141,89E -146,0 315.41 307.60 1500,00 1441.22 270.208 104,67W M-3 1443,08 1442,90 3.998 141,48E -149,0 362,58 354,10 1600.00 1521,96 326.918 120,87W M-3 1521.68 1521.50 3,998 141.13E -151.2 415.83 407.09 1700.00 1598.97 388,398 137.76W M-3 1581,78 1581,58 2,728 141.41E -152,3 476.43 467.42 RECEIVED APR 2 9 2005 Alaska Oil & Gas Cons. Commission Anchorage All data is in Feet unless otherwise stated Coordinates are from 810t and TVD's are from Rig ( Planned Datum 160.3ft 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 (10) Casings Included Prepared by Baker Hughes Incorporated · e UNOCAL. UNOCAL M-17 V4, M-17 V4 slot #A 1-9, STEELHEAD Platform CLEARANCE LISTING Page 18 Date Printed: 28-Mar-2005 McArthur River Field, TBU, Cook Inlet, Alaska 0,00 0.00 O,OON O,OOE M-4 0,00 0,00 20.97N 150,94E 82.1 152.39 150,06 16.40 16.40 O.OON O,OOE M4 16.40 16.40 20,97N 150,94E 82,1 152,39 149,79 100,00 100,00 O.OON O.OOE M4 100,00 100.00 20.97N 150.94E 82,1 152.39 149.41 200.00 200.00 O,OON O.OOE M4 200.00 200,00 20.97N 150,94E 82.1 152.39 148.79 300,00 300.00 O.OON O,OOE M-4 300,00 300,00 20,97N 150,94E 82.1 152,39 148.16 300,00 300,00 O.OON O,OOE M4 300,00 300,00 20.97N 150.94E 82.1 152.39 148.16 400.00 400.00 O,OON O.OOE M4 399.18 399,17 20,22N 151,29E 82.4 152,64 148,10 480.00 480,00 O.OON O,OOE M4 479.45 479.44 19,09N 151,78E 82.8 152,98 148.05 500,00 500,00 O.OON O,OOE M4 498,27 498.25 19,14N 151.95E 82,8 153,16 149.22 600.00 599,94 2,508 1.75W M4 596,85 596,80 20.95N 153,26E -133,5 156.81 152.59 700.00 699.50 9,998 7.00W M-4 695.54 695,37 25,76N 154,51 E -137,2 165.47 161,02 721.78 721.11 12,298 8,60W M4 715,38 715.16 27,08N 154,78E -138,1 168,16 163.66 750,00 749,03 15,618 10.93W M4 741,35 741.05 28.94N 155.29E -139,4 172.26 167.69 800.00 798,33 22.588 15,43W M4 788.15 787,69 32.59N 156,70E -137,9 181.07 176.33 900.00 896.12 40,968 25.24W M-4 883,34 882.47 40,81N 160,09E -138,3 203.02 198,21 1000.00 992,52 65,198 36.11W M4 972,91 971.52 49.83N 163.37E -140,5 231.21 225.95 1100.00 1087.16 95.188 47,98W M4 1055,72 1053,57 60.39N 167.04E -143,2 267.52 261.82 1200,00 1179.68 130,828 60,83W M-4 1129.72 1126.46 72.41 N 171,02E -145,6 312,87 306,66 1300.00 1269,76 171.988 74.59W M4 1200.04 1195.19 86.49N 175.91 E -147,8 367,58 360.80 1400.00 1357.05 218,508 89,22W M4 1263,00 1256,32 100,53N 181,33E -149,3 430.25 422,93 1500.00 1441.22 270.208 104,67W M4 1322.02 1313.29 114.95N 186,77E -150.2 499,64 491 ,78 RECEIVED ,APR 2 9 2005 Alaska Oil & Gas C(,!Il~, Anchore~e All data is in Feet unless otherwise stated Coordinates are from 810t and TVO's are from Rig ( Planned Datum 160,3ft 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 (1 D) Casings Included Prepared by Baker Hughes Incorporated · e UNOCALe UNOCAL M-17 V4, M-17 V4 slot #A1-9, STEELHEAD Platform CLEARANCE LISTING Page 19 Date Printed: 28-Mar-2005 McArthur River Field, TaU, Cook Inlet, Alaska 0.00 0,00 O.OON O.OOE M-12 0,01 0.01 12,03N 2,88E 13,5 12,37 10.03 100.00 100,00 O,OON O,OOE M-12 100,01 100.01 11.99N 2,88E 13.5 12.33 9.36 200.00 200.00 O.OON O,OOE M-12 200.01 200,01 11.94N 2.87E 13.5 12.28 8.68 300,00 300,00 O.OON O.OOE M-12 300,02 300.02 11,85N 2.73E 13,0 12,16 7,92 350.00 350,00 O,OON O,OOE M-12 350.00 350,00 11.79N 2,63E 12.6 12.08 7.51 400.00 400.00 O.OON O,OOE M-12 400.00 400,00 11,81 N 2.59E 12,4 12,09 7,22 442,91 442,91 O,OON O.OOE M-12 442,89 442.89 11.88N 2,55E 12.1 12,15 7.20 459.32 459.32 O,OON O,OOE M-12 459.24 459,24 11.94N 2.52E 11,9 12.21 7.22 475,72 475.72 O.OON O,OOE M-12 475,64 475.64 12,06N 2.47E 11,6 12,32 7,29 480.00 480,00 O,OON O,OOE M-12 479,81 479,80 12.12N 2,45E 11.4 12.37 7.34 500,00 500,00 O.OON O,OOE M-12 499.80 499,80 12.4 7N 2.32E 10,6 12.69 8,73 600.00 599,94 2,508 1.75W M-12 597,85 597.45 20.51N O,29E 149,8 23.23 19,14 700.00 699.50 9,998 7.00W M-12 696.49 695,32 31.63N 4.90W 147.3 41.89 37.55 750,00 749,03 15,618 10,93W M-12 746,51 744.84 36,19N 10,14W 145.2 51,97 47.48 800.00 798,33 22.588 15,43W M-12 796,13 793,87 39.78N 16,84W 146,9 62.54 57.89 900,00 896.12 40.968 25.24W M-12 893,98 890,42 45,75N 31.55W 148.8 87.13 82.43 1000.00 992,52 65,198 36,11W M-12 985,95 981.23 51,91 N 44,73W 151.2 117,96 112.83 1100,00 1087.16 95.188 47,98W M-12 1069.81 1064,08 61.13N 53,64W 154,6 158.10 152.59 1200,00 1179.68 130.828 60.83W M-12 1147,98 1141.03 74.08N 57.93W 158.3 208,53 202.60 1300.00 1269,76 171.98S 74,59W M-12 1221.10 1212.62 88,92N 58,56W 161,8 267,56 261 .43 1400.00 1357,05 218,508 89,22W M-12 1281,72 1271.48 103,29N 56,74W 164,5 334.55 328.21 1500,00 1441.22 270.208 104,67W M-12 1337,70 1325,30 118,24N 53.10W 166.8 408.63 402,07 1600.00 1521,96 326.918 120.87W M-12 1384.17 1369.49 131.78N 48.42W 168,7 488,76 482.23 RECEIVED APR 2 9 Z005 Alaska Oil & Gas Conß. Comm¡~~¡on Anchorage All data is in Feet unless otherwise stated Coordinates are from 810t and TVD's are from Rig (Planned Datum 160,3ft 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) Casings Included Prepared by Baker Hughes Incorporated · e UNOCALe UNOCAL M-17 V4, M-17 V4 slot #A 1-9, STEELHEAD Platform CLEARANCE LISTING Page 20 Date Printed: 28-Mar-2005 McArthur River Field, TBU, Cook Inlet, Alaska 0.00 0,00 O,OON O.OOE M-12 0.01 0.01 12,03N 2.88E 13,5 12,37 10.03 100.00 100.00 O,OON O.OOE M-12 100,01 100.01 11,99N 2,88E 13.5 12,33 9.36 200.00 200.00 O.OON O,OOE M-12 200.01 200,01 11.94N 2.87E 13.5 12.28 8.68 300,00 300,00 O.OON O.OOE M-12 300,02 300.02 11,85N 2.73E 13,0 12.16 7.92 350.00 350.00 O,OON O.OOE M-12 350,00 350.00 11,79N 2,63E 12,6 12,08 7.51 400.00 400.00 O,OON O,OOE M-12 400.00 400,00 11.81 N 2.59E 12.4 12.09 7.22 459.32 459.32 O.OON O,OOE M-12 459.26 459,26 11,87N 2.49E 11,9 12.13 6.92 480,00 480,00 O.OON O.OOE M-12 479,81 479.80 12,16N 2.36E 11,0 12,39 7,12 500.00 500.00 O,OON O.OOE M-12 499,59 499.58 12,78N 2,13E 9.5 12,96 8.74 600.00 599.94 2,50S 1,75W M-12 597.57 597,14 21.08N 0.31W 148,2 23.79 19,48 700,00 699.50 9.995 7,OOW M-12 694.83 693,46 34,09N 3.62W 148.7 44.62 40.16 750.00 749,03 15,61S 10,93W M-12 742,92 741.06 40,84N 5,10W 150.0 57,30 52.74 800.00 798.33 22.585 15.43W M-12 790.34 787,94 47.77N 6.39W 155,3 71.69 67,01 900,00 896.12 40,965 25,24W M-12 809.00 806,39 50,56N 6.87W 160.6 129.48 125.06 1000.00 992,52 65.195 36,11W M-12 809,00 806.39 50,56N 6,87W 162.9 221,12 216.62 1100,00 1087,16 95.185 47,98W M-12 809,00 806.39 50,56N 6,87W 163,2 318.99 314.34 1200,00 1179.68 130,825 60.83W M-12 809.00 806,39 50.56N 6.87W 158,1 418.52 413.68 RECEIVED APR 2 9 2005 Alaska Oil & Gas Cons. Commission Anch¡m~ge All data is in Feet unless otherwise stated Coordinates are from 510t and TVO's are from Rig ( Planned Datum 160.3ft 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 (1 D) Casings Included Prepared by Baker Hughes Incorporated . . UNOCALe UNOCAL M-17 V4, M-17 V4 slot #A1-9, STEELHEAD Platform CLEARANCE LISTING Page 21 Date Printed: 28-Mar-2005 McArthur River Field, TBU, Cook Inlet, Alaska 0.00 0,00 O,OON O.OOE M-13 0,00 7,95 4,70N 2.34W -26,5 9.53 7.19 7.95 7.95 O.OON O,OOE M-13 0,00 7.95 4.70N 2.34W -26.5 5,25 2,87 100,00 100,00 O.OON O.OOE M-13 92,05 100,00 4,69N 2,38W -26,9 5.26 2.54 200.00 200.00 O.OON O,OOE M-13 192,05 200.00 4.65N 2,36W -26,9 5,22 2,11 300.00 300.00 O,OON O.OOE M-13 292.06 300,01 4,53N 2.24W -26.4 5.05 1.55 400,00 400,00 O.OON O.OOE M-13 392,07 400.02 4.18N 2,19W -27,7 4,72 0.83 480.00 480.00 O,OON O,OOE M-13 472.06 4BO,01 3.78N 2.35W -31.9 4.45 0,24 500,00 500,00 O.OON O,OOE M-13 492,06 500.01 3,67N 2,43W -33,5 4.41 1.23 507.94 507.94 0,025 O,01W M-13 500,00 507,95 3.63N 2.46W -33.9 4,40 1,20 600,00 599,94 2,50S 1.75W M-13 591,99 599,93 3,13N 3,70W 125,9 5.96 2.61 700.00 699.50 9.995 7,OOW M-13 691.81 699,69 2.0BN 6,97W 145,0 12,07 8,53 750,00 749,03 15.615 10.93W M-13 741,72 749,53 1,10N 9.46W 149.9 16.78 13.12 800.00 798.33 22,585 15.43W M-13 791,50 799.19 0.265 12.44W 156,4 22,54 18.77 900,00 896,12 40.965 25,24W M-13 890,83 898,16 3,975 20,05W 161.8 37.41 33.70 1000,00 992.52 65.195 36.11W M-13 989,66 996.31 8.815 30.45W 162,6 56,79 52,82 1100.00 1087,16 95.185 47,98W M-13 1087,48 1092,91 14,595 44.72W 161.0 80.86 76.74 1200,00 1179.68 130,825 60,83W M-13 1184.88 1188,36 21.56S 62,72W 158,9 109,62 105.26 1300.00 1269,76 171,985 74,59W M-13 1282,42 1283,10 30,595 84,06W 156.8 142.33 137,60 1400.00 1357.05 218.505 89,22W M-13 1378.31 1375.29 41.735 107,96W 155,0 178.69 173.47 1500,00 1441.22 270,205 104,67W M-13 1472,77 1465,24 54,345 133.86W 153.5 219,15 213,34 1600.00 1521,96 326.915 120.87W M-13 1568.61 1554.78 69,715 164,32W 151,7 262.90 256.63 1700,00 1598.97 388,395 137,76W M-13 1663,91 1641,50 88.125 199.27W 149,5 309.44 302,31 1800.00 1671,96 454.44S 155.29W M-13 1756.48 1723.45 108.425 237,19W 147,2 359.28 351.16 1900,00 1740.66 524,795 173,39W M-13 1844,92 1799.48 129.725 277.01W 144.9 412,65 403,43 2000.00 1804,82 599.195 191.98W M-13 1932.81 1872.90 152.465 319,62W 142,7 469.57 459.13 2046,79 1833.21 635,315 200,83W M-13 1972,10 1905,03 163,145 339.56W 141.6 497,34 486,31 RECEIVED APR 2 9 Zo05 Alaska Oìl & Gas Cons. Commissíon Anchorage All data is in Feet unless otherwise stated Coordinates are from 510t and TVO's are from Rig ( Planned Datum 160,3ft 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 (1 D) Casings Included Prepared by Baker Hughes Incorporated . . UNOCAL. UNOCAL M-17 V4, M-17 V4 slot #A 1-9, STEELHEAD Platform CLEARANCE LISTING Page 22 Date Printed: 28-Mar-2005 McArthur River Field, TBU, Cook Inlet, Alaska 0.00 0,00 O.OON O,OOE M-19 0.00 0.00 3.38N 11,39E 73.5 11.88 9.55 0,00 0.00 O,OON O,OOE M-19 0,00 0,00 3.38N 11.39E 73,5 11,88 9,55 16,40 16.40 O,OON O,OOE M-19 16,40 16,39 3,35N 11.41E 73,7 11,89 9,43 100.00 100,00 O,OON O.OOE M-19 99,97 99,97 3,OON 11,66E 75,6 12.05 9,311 200,00 200,00 O,OON O.OOE M-19 199,97 199,97 2,46N 12,08E 78.5 12.33 9.34 246,06 246.06 O.OON O.OOE M-19 246,03 246.03 2.32N 12,24E 79.3 12.46 9.30 300.00 300,00 O.OON O,OOE M-19 299,95 299.95 2,18N 12.49E 80.1 12.68 9.35 360.89 360.89 O.OON O,OOE M-19 360,73 360.73 2.09N 13.02E 80.9 13,19 9.65 400.00 400.00 O,OON O,OOE M-19 399,84 399.83 2.08N 13.52E 81.3 13,68 10.03 459.32 459.32 O.OON O,OOE M-19 458,98 458.96 1.97N 14.68E 82,4 14,82 10,97 480.00 480.00 O,OON O,OOE M-19 479.66 479,63 1.87N 15.20E 83,0 15,32 11.42 500.00 500,00 O,OON O.OOE M-19 499.65 499,61 1.77N 15.70E 83,6 15,80 12.95 600.00 599,94 2,508 1.75W M-19 599.26 599,15 O,14N 19,25E -132.0 21.18 18.15 700.00 699,50 9.998 7.00W M-19 698,56 698,29 3,008 23.79E -137,4 31.60 28.37 750,00 749,03 15,618 10,93W M-19 748,15 747,78 5,158 26,17E -140,2 38.57 35.23 800,00 798,33 22,588 15.43W M-19 797,62 797.12 7,838 28.50E -138,9 46.35 42,91 900.00 896.12 40,968 25.24W M-19 895,74 894.86 14.688 33,56E -139,0 64.41 61.04 1000,00 992.52 65.198 36.11 W M-19 992.44 991.18 21.498 38,94E -141,5 86,85 83.21 1100,00 1087.16 95.188 47,98W M-19 1087,01 1085.53 25.798 43.44E -145.9 114,78 110.94 1200,00 1179.68 130,828 60,83W M-19 1180,24 1178,69 27,808 46.47E -150.7 148,75 144.64 1300.00 1269,76 171,988 74,59W M-19 1273,77 1272,20 29.298 47.88E -154.9 188,05 183,65 1400,00 1357,05 218,508 89,22W M-19 1361,07 1359,48 30.918 47.99E -158.1 232,43 227,73 1500.00 1441,22 270,208 104.67W M-19 1444,36 1442,76 31,878 48.24E -160,4 283.17 278.16 1600.00 1521,96 326.918 120.87W M-19 1520,44 1518,84 31,948 48.77E -162,0 340.28 335,24 1700.00 1598,97 388.398 137.76W M-19 1584,51 1582.88 30,418 49.38E -163,0 404.26 398,96 1800.00 1671,96 454.448 155,29W M-19 1645.70 1643.99 27,218 49.83E -163,7 474.74 469.19 RECEI\IED APR 2 9 2005 Alaska Oil &G8s Con~.. Anchorage All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Datum 160,3ft 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) Casings Included Prepared by Saker Hughes Incorporated . . UNOCALe UNOCAL M-17 V4, M-17 V4 slot #A1-9, STEELHEAD Platform CLEARANCE LISTING Page 23 Date Printed: 28-Mar-2005 McArthur River Field, TBU, Cook Inlet, Alaska 0.00 0.00 O,OON O,OOE 81-8 0,45 -0,30 82.00N 62.57E 37,4 103,15 100,80 100,00 100,00 O,OON O,OOE 81-8 100,67 99.92 82.19N 62.63E 37,3 103.34 100.37 200,00 200,00 O,OON O.OOE 81-8 201 ,18 200.43 82.06N 62,63E 37.4 103,23 99.63 300,00 300,00 O.OON O.OOE 81-8 301,05 300.30 81.56N 62,60E 37.5 102.82 98.58 349.25 349.25 O.OON O,OOE 81-8 350,00 349,25 81,39N 62,65E 37.6 102,72 98.16 400.00 400.00 O,OON O,OOE 81-8 400,12 399,36 81,66N 62.67E 37,5 102,94 98.08 480,00 480.00 O,OON O,OOE 81-8 480.43 479,67 82.55N 62.23E 37,0 103,38 98.06 500,00 500,00 O.OON O.OOE 81-8 501,37 500,61 82.66N 62,06E 36.9 103.36 99.02 600.00 599.94 2.50S 1,75W 81-8 604,18 603.39 81,22N 60,52E -178,4 104.40 99,78 700.00 699.50 9.99S 7,OOW 81-8 704,70 703.84 78,56N 57.82E -178,8 109,83 104.92 738.19 737.35 14.17S 9.92W 81-8 742,80 741,91 77.49N 56.71E -179.0 113,41 108,38 750.00 749,03 15.61S 10.93W 81-8 754.28 753,38 77.19N 56.37E -179.0 114.71 109,63 800,00 798,33 22.58S 15,43W 81-8 804,17 803,24 75.86N 54,96E -175.4 121,11 115,84 900,00 896,12 40,96S 25,24W 81-8 857,00 856,01 74.12N 53,44E -170,6 145.06 139.86 1000.00 992,52 65,19S 36,11W 81-8 857,00 856.01 74.12N 53,44E -166,1 214.61 209.51 1100,00 1087.16 95,18S 47.98W 81-8 857,00 856.01 74,12N 53.44E -160,7 303,93 298,85 1200,00 1179.68 130,82S 60.83W 81-8 857,00 856,01 74,12N 53.44E -152.8 399,78 394,60 1300,00 1269.76 171,98S 74,59W 81-8 857.00 856,01 74,12N 53.44E -138.5 498,14 492,81 RECE,\IF APR 2 9 2.005 Alaska Oil & Anchorfige All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig (Planned Datum 160.3f1 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) Casings Included Prepared by 8aker Hughes Incorporated . . UNDCALe UNOCAL M-17 V4, M-17 V4 slot #A 1-9, STEELHEAD Platform CLEARANCE LISTING Page 24 Date Printed: 28-Mar-2005 McArthur River Field, TBU, Cook Inlet, Alaska 1082.68 1070,90 89,588 45,85W RLF #1 1533.38 1431.48 2 ,158 297,64E -134,7 502.15 492.96 1100.00 1087.16 95,18S 47.98W RLF #1 1541.57 1435.73 20.638 292.30E -135,8 492,80 483.42 1200,00 1179.68 130,828 60.83W RLF #1 1585,13 1458,21 3.30N 263,66E -141.1 448,17 437,42 1300,00 1269,76 171,988 74,59W RLF #1 1617,25 1474,20 21.23N 242,36E -144.9 423.77 411.47 1345.14 1309,53 192.328 81,09W RLF #1 1629.50 1480.21 28.18N 234.25E -146.2 420.94 407.88 1400,00 1357.05 218.508 89,22W RLF #1 1643.34 1486.99 36,02N 225,09E -147.5 424.80 410.96 1459,97 1407.92 248,908 98.39W RLF #1 1657,10 1493,74 43,83N 215,98E -148.6 438,04 423,45 1500.00 1441,22 270,208 104,67W RLF#1 1661.42 1495,86 46.29N 213,14E -148.6 451,84 436.93 1600.00 1521,96 326,918 120.87W RLF #1 1679,24 1504.62 56.51N 201.46E -149,3 501.20 485.90 RECEI\/ED .!\PR 2 9 2005 Alaska Oil & Gas Con~, Comrni$sioi\ Al1chorega All data is in Feet unless otherwise stated Coordinates are from 810t and TVD's are from Rig ( Planned Datum 160.3ft 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) Casings Included Prepared by Baker Hughes Incorporated . . UIIOCALe UNOCAL M-17 V4, M-17 V4 slot #A1-9, STEELHEAD Platform CLEARANCE LISTING Page 25 Date Printed: 28-Mar-2005 McArthur River Field, TBU, Cook Inlet, Alaska 0,00 0.00 O,OON O.OOE M-14 0,00 7,95 3,76N 7,43E 63.2 11.51 9.18 7.95 7,95 O.OON O.OOE M-14 0.00 7.95 3.76N 7.43E 63.2 8.33 5.94 100.00 100.00 O.OON O,OOE M-14 92,06 100,01 3.67N 7.44E 63,7 8,29 5,58 200.00 200.00 O,OON O,OOE M-14 192.06 200,01 3.38N 7.44E 65,6 8.17 5,07 300.00 300,00 O,OON O.OOE M-14 292.06 300,01 3,02N 7,44E 68.0 8.03 4.53 400,00 400,00 O,OON O.OOE M-14 392.07 400.01 2,56N 7,45E 71.0 7.87 3.99 480.00 480,00 O.OON O.OOE M-14 472,07 480.01 2.04N 7.48E 74.7 7,75 3.55 482.95 482.95 O,OON O,OOE M-14 475,00 482,95 2.02N 7.48E 74,9 7,75 3,53 500.00 500.00 O,OON O,OOE M-14 492.07 500,01 1,93N 7.48E 75,5 7.72 4.55 600,00 599,94 2,505 1.75W M-14 592,03 599,97 1,16N 7,45E -146,6 9.90 6.47 700,00 699,50 9.998 7,OOW M-14 691,68 699.62 0.31N 7.30E -160.7 17,63 13.91 750.00 749.03 15,618 10.93W M-14 741.29 749,23 0.168 7.18E -165.3 23.80 19.92 800.00 798,33 22.588 15.43W M-14 790.70 798,64 0,668 7.01E -165,1 31.37 27,33 900,00 896,12 40,968 25,24W M-14 888,98 896.91 1,928 6,43E -166,5 50.28 46,22 1000,00 992,52 65,198 36,11W M-14 985,87 993.77 3.598 5,83E -168,1 74.53 70,15 1100,00 1087.16 95,188 47.98W M-14 1080,84 1088,73 5.068 5.35E -169.4 104,74 100,13 1200.00 1179.68 130.828 60.83W M-14 1173,71 1181,59 6.368 4.97E -170.5 140.79 135,91 1300.00 1269,76 171,988 74,59W M-14 1263,77 1271,64 7,428 4.66E -171.3 182.66 177.48 1400.00 1357,05 218.508 89,22W M-14 1350.58 1358.45 8,258 4,54E -171,9 230.21 224.72 1500,00 1441,22 270.208 104,67W M-14 1434.46 1442.34 8.778 4,66E -172,3 283,37 277.54 1600,00 1521.96 326,918 120,87W M-14 1514,45 1522,32 9.028 4,82E -172.5 341,83 335,93 1700.00 1598,97 388,39S 137.76W M-14 1591.41 1599,28 9,128 4.88E -172.7 405.21 398.98 1800.00 1671,96 454.44S 155.29W M-14 1664.42 1672.29 9.178 4,91E -172.8 473.20 466.64 RECEIVED APR 2 9 2005 Alaska Oil & G$)I! Cons. Commission Anch¡)(¡~ge All data is in Feet unless otherwise stated Coordinates are from 810t and TVD's are from Rig ( Planned Datum 160,3ft 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 OJ Casings Included Prepared by Baker Hughes Incorporated . . UNOCALe UNOCAL M-17 V4, M-17 V4 slot #A 1-9, STEELHEAD Platform CLEARANCE LISTING Page 26 Date Printed: 28-Mar-2005 McArthur River Field, TBU, Cook Inlet, Alaska 0,00 0.00 O,OON O,OOE M-14 0,00 7,95 3,76N 7,43E 63.2 11.51 9.18 7.95 7,95 O.OON O.OOE M-14 0.00 7.95 3,76N 7,43E 63.2 8,33 5.94 100.00 100.00 O.OON O,OOE M-14 92,06 100,01 3.67N 7.44E 63,7 8,29 5,58 200.00 200.00 O,OON O.OOE M-14 192.06 200,01 3,38N 7.44E 65.6 8.17 5.07 300,00 300,00 O,OON O.OOE M-14 292,06 300,01 3,02N 7,44E 68.0 8.03 4.53 400,00 400,00 O.OON O.OOE M-14 392,07 400.01 2.56N 7.45E 71,0 7,87 3,99 480.00 480.00 O.OON O,OOE M-14 472.07 480,01 2.04N 7.48E 74,7 7.75 3.55 482.95 482.95 O,OON O.OOE M-14 475.00 482.95 2,02N 7,48E 74.9 7.75 3.53 500,00 500,00 O.OON O.OOE M-14 492,07 500.01 1,93N 7.48E 75,5 7,72 4,55 600,00 599,94 2.50S 1,75W M-14 592,03 599,97 1.16N 7.45E -146.6 9,90 6.47 700.00 699.50 9,99S 7,OOW M-14 691.68 699,62 0.31N 7.30E -160.7 17.63 13.91 750,00 749,03 15.61S 10,93W M-14 741,29 749.23 O,16S 7,18E -165,3 23.80 19,92 800,00 798,33 22,58S 15.43W M-14 790,70 798.64 0.66S 7,01E -165,1 31,37 27.33 900.00 896,12 40,96S 25.24W M-14 888,98 896,91 1.92S 6.43E -166.5 50,28 46.22 1000,00 992.52 65.19S 36.11W M-14 985.87 993,77 3,59S 5.83E -168,1 74.53 70,15 1100.00 1087,16 95,18S 47,98W M-14 1080,84 1088.73 5,06S 5,35E -169.4 104.74 100.13 1200.00 1179.68 130.82S 60.83W M-14 1173.71 1181,59 6.36S 4.97E -170.5 140,79 135,91 1300,00 1269.76 171,98S 74.59W M-14 1263,77 1271,64 7.42S 4.66E -171.3 182,66 177.48 1400,00 1357.05 218,50S 89,22W M-14 1350,58 1358.45 8,25S 4.54E -171,9 230.21 224.72 1500.00 1441,22 270.20S 104.67W M-14 1434.46 1442.34 8.77S 4,66E -172.3 283,37 277.54 1600.00 1521.96 326.91 S 120,87W M-14 1514,45 1522,32 9.02S 4.82E -172.5 341.83 335,93 1700,00 1598.97 388,39S 137,76W M-14 1591.41 1599,28 9,12S 4,88E -172,7 405.21 398.98 1800.00 1671,96 454.44S 155.29W M-14 1664.42 1672.29 9.17S 4,91E -172.8 473,20 466.64 M-14 M-14 PGMS <2700-9101 '> 9190,00 Gyrodata Unknown Gyro Type 1-Sep-0 THJ Unknown Gyro Type 1-Sep-0 THJ RECEIVED APR 2 9 2005 Alaska Oil &. Gûs Cm)~. Anchor;¡ge All data is in Feet unless otherwise stated Coordinates are from Slot and TVO's are from Rig (Planned Oatum 160.3ft 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) Casings Included Prepared by Baker Hughes Incorporated . . UNOCAL. UNOCAL M-17 V4, M-17 V4 slot #A 1-9, STEELHEAD Platform CLEARANCE LISTING Page 27 Date Printed: 28-Mar-2005 McArthur River Field, TBU, Cook Inlet, Alaska 0,00 0.00 O.OON O.OOE M-9 0.00 0.00 16.97N 152.60E 83.7 153.54 151,21 16,40 16.40 O.OON O,OOE M-9 16.26 16.26 17.00N 152.61 E 83.7 153.56 151.02 100.00 100,00 O,OON O,OOE M-9 100,28 100.28 17,01 N 152.62E 83.6 153.56 150.60 175.00 175.00 O,OON O,OOE M-9 175,00 175.00 16,66N 152.56E 83.8 153.47 150.01 200.00 200.00 O,OON O,OOE M-9 199,82 199,82 16,64N 152,59E 83.8 153.50 149.90 300.00 300.00 O,OON O,OOE M-9 299,88 299,88 16,59N 152,63E 83,8 153.53 149.29 400,00 400.00 O,OON O,OOE M-9 399.97 399,97 16,04N 152,71 E 84.0 153,55 148.68 480,00 480,00 O,OON O,OOE M-9 479.61 479,60 16,07N 153,03E 84,0 153,87 148.50 500,00 500,00 O,OON O.OOE M-9 499.46 499,46 16.06N 153,09E 84,0 153,93 149.54 600,00 599,94 2,508 1.75W M-9 594,76 594,74 16.93N 154,70E -131.9 157,74 153,09 639,76 639,59 4.888 3.42W M-9 631,21 631,14 17.85N 156,10E -132.8 161,35 156,62 700.00 699.50 9.998 7,OOW M-9 687,66 687.47 19.88N 159.29E -134,6 169.38 164.50 750.00 749.03 15,61 S 10,93W M-9 732,87 732.50 22.00N 162.74E -136,3 178.46 173.44 800.00 798.33 22.58S 15.43W M-9 778,39 777.74 24,51N 166.99E -134,2 189.52 184.33 900.00 896.12 40,968 25.24W M-9 871.54 870.21 29,87N 176.94E -133,2 215.79 210.52 1000,00 992.52 65.198 36.11W M-9 960,88 958.81 35,57N 186.82E -134,1 246.95 241.24 1100.00 1087.16 95,188 47,98W M-9 1037,00 1033,86 43,10N 196,99E -135,4 286,31 280.20 1200,00 1179,68 130,828 60,83W M-9 1102,23 1097,54 52,55N 207,38E -136.7 335,12 328.54 1300.00 1269.76 171.988 74,59W M-9 1162.15 1155.11 64.96N 218.44E -137,8 393,89 386.78 1400.00 1357,05 218,508 89,22W M-9 1212,73 1202,97 78,18N 228,05E -138.4 460,88 453,28 RECE"/FD; APR 2 9 2005 Alaska Oil .& AnchorÐfJe All data is in Feet unless otherwise stated Coordinates are from 810t and TVD's are from Rig ( Planned Datum 160,3ft 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) Casings Included Prepared by Baker Hughes Incorporated . . UROCAL. UNOCAL M-17 V4, M-17 V4 slot #A 1-9, STEELHEAD Platform CLEARANCE LISTING Page 28 Date Printed: 28-Mar-2005 McArthur River Field, TBU, Cook Inlet, Alaska 0.00 0.00 O,OON O,OOE M-5 0,00 7,95 16,17N 142.46E 83,5 143,60 141,26 16.40 16,40 O,OON O.OOE M-5 8.45 16.40 16.17N 142.46E 83,5 143.38 140.84 100,00 100,00 O.OON O.OOE M-5 92,05 100.00 16.17N 142.46E 83.5 143.38 140.43 200,00 200.00 O.OON O.OOE M-5 192,02 199.97 16,19N 142.48E 83.5 143.40 139.83 300.00 300.00 O.OON O,OOE M-5 292,02 299.97 16,21 N 142.50E 83.5 143,42 139.22 400.00 400.00 O.OON O,OOE M-5 392,27 400.22 16,13N 142,42E 83,5 143,33 138,50 480.00 480.00 O,OON O,OOE M-5 473.03 480,98 16,02N 142,08E 83,6 142,98 137,64 500,00 500,00 O,OON O,OOE M-5 493,03 500,98 16,OON 141,94E 83,6 142,85 138.49 524,93 524,93 0.168 O,11W M-5 518,13 526.07 15.98N 141.75E -131,5 142.78 138.29 600,00 599.94 2.508 1,75W M-5 593,14 601.09 15,91 N 141.16E -132,3 144.10 139.24 700,00 699.50 9.998 7,OOW M-5 693,20 701.14 15,85N 140,19E -134,8 149,45 144.08 750.00 749.03 15.618 10.93W M-5 742,90 750,84 15,86N 139,60E -136.5 153,79 148.15 800.00 798,33 22.588 15,43W M-5 792.26 800,19 15.87N 139,01 E -134.6 159.16 153,25 836.61 834,28 28.638 18,90W M-5 828,19 836.13 15.89N 138.58E -134,1 163.65 157.54 900,00 896.12 40,968 25,24W M-5 890,10 898,03 15.92N 137.84E -134.4 172.73 166.58 951.44 945.91 52,708 30,70W M-5 939,69 947.61 16,03N 137.28E -135,4 181,50 175.06 1000,00 992.52 65.198 36,11 W M-5 985.77 993,69 16,30N 136,81 E -136.8 191,16 184.44 1100,00 1087.16 95.188 47.98W M-5 1079,54 1087.45 17,03N 136,07E -140.2 215,56 208,33 1200.00 1179.68 130,828 60,83W M-5 1171,00 1178,91 17.80N 135,63E -143.7 246,35 238,50 1300.00 1269,76 171,988 74,59W M-5 1260.41 1268.31 18.73N 135.35E -147,1 283.64 275,13 1400.00 1357,05 218.508 89,22W M-5 1347.03 1354.92 19,77N 135.04E -150,0 327.21 318.06 1500,00 1441.22 270.208 104,67W M-5 1429,63 1437,52 20,89N 134,81 E -152.4 376,95 367.27 1600,00 1521.96 326,918 120,87W M-5 1507,60 1515,47 22,31 N 134,55E -154,3 432,70 422,94 1700.00 1598,97 388,398 137.76W M-5 1583,36 1591,22 23.89N 134.30E -155,9 494.02 483.93 RECEIVED APR 2 9 2005 Alaska Oil & Gas Cons. C(¡mm¡~s¡on Anchorage All data is in Feet unless otherwise stated Coordinates are from 810t and TVO's are from Rig (Planned Oatum 160.3ft 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) Casings Included Prepared by Baker Hughes Incorporated . . UtlOCALe UNOCAL M-17 V4, M-17 V4 slot #A1-9, STEELHEAD Platform CLEARANCE LISTING Page 29 Date Printed: 28-Mar-2005 McArthur River Field, TBU, Cook Inlet, Alaska 0.00 0,00 O.OON O.OOE 81-2 0,17 0.17 87.03N 73,60E 40.2 113.98 111.64 100.00 100.00 O.OON O,OOE 81-2 99,62 99.62 86,92N 73.53E 40,2 113,85 110,89 200.00 200,00 O,OON O,OOE 81-2 200.27 200,27 86.71N 73.53E 40,3 113,69 110.09 300,00 300,00 O,OON O.OOE 81-2 300,29 300,29 86.27N 73,59E 40.5 113.39 109.16 325,00 325,00 O.OON O.OOE 81-2 325,00 325.00 86,16N 73,61 E 40.5 113.33 108.93 360.89 360.89 O.OON O,OOE 81-2 360.43 360,43 86.13N 73.72E 40,6 113,37 108,75 400.00 400.00 O,OON O,OOE 81-2 398.39 398,38 86.51N 73.98E 40,5 113.84 108,99 480,00 480,00 O,OON O.OOE 81-2 479,56 479.54 87.55N 74,27E 40.3 114.81 109.44 500,00 500.00 O.OON O.OOE 81-2 498,06 498.05 87,70N 74,37E 40.3 115.00 110.70 508.53 508.53 0,025 O,01W 81-2 506.59 506,57 87,74N 74.54E -174.7 115,17 110,86 600.00 599,94 2,505 1,75W 81-2 595.02 594,89 87.83N 78,80E -173.3 121.14 116.74 700,00 699,50 9.995 7,OOW 81-2 693,63 693.36 88,94N 84,OOE -172,3 134.56 129.99 750.00 749.03 15.615 10.93W 81-2 743.03 742.69 89.87N 86,27E -172,2 143,57 138.86 800.00 798.33 22.585 15.43W 81-2 792.18 791,79 90.93N 88.25E -168.3 153,87 149,02 900,00 896.12 40,965 25,24W 81-2 889,27 888.79 92.89N 92,11 E -164,1 178.16 173.28 1000.00 992,52 65,195 36.11W 81-2 984,81 984.21 94,14N 96.62E -162,0 207.53 202.31 1100,00 1087.16 95.185 47.98W 81-2 1020,00 1019,36 94.51 N 98.37E -159.8 249.00 243.62 1200.00 1179,68 130.825 60,83W 81-2 1020.00 1019.36 94.51N 98,37E -156,6 319.10 313.61 1300,00 1269.76 171.985 74,59W 81-2 1020.00 1019.36 94,51N 98.37E -152,3 404,52 398.90 1400,00 1357.05 218,505 89.22W 81-2 1020,00 1019,36 94,51 N 98.37E -146.1 497,19 491.42 RECEI\/ED APR 2 )j Z005 Alaska Oil & Gas Cons. Commì&s¡on Anchorage All data is in Feet unless otherwise stated Coordinates are from 510t and TVD's are from Rig (Planned Datum 160,3ft 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 (10) Casings Included Prepared by 8aker Hughes Incorporated . . UNOCAL8 UNOCAL M-17 V4, M-17 V4 slot #A 1-9, STEELHEAD Platform CLEARANCE LISTING Page 30 Date Printed: 28-Mar-2005 McArthur River Field, TBU, Cook Inlet, Alaska 0,00 0.00 O,OON O,OOE B1-2 0.17 0.17 87,03N 73.60E 40,2 113,98 111.64 100,00 100,00 O,OON O,OOE B1-2 99,62 99,62 86.92N 73.53E 40,2 113,85 110.89 200,00 200,00 O,OON O.OOE B1-2 200.27 200,27 86.71N 73,53E 40,3 113.69 110,09 300,00 300.00 O.OON O,OOE B1-2 300,29 300.29 86.27N 73,59E 40.5 113.39 109.16 325.00 325.00 O,OON O,OOE B1-2 325,00 325.00 86,16N 73.61 E 40.5 113.33 108.93 360.89 360,89 O,OON O,OOE B1-2 360.43 360,43 86,13N 73.72E 40,6 113,37 108.75 400,00 400,00 O,OON O,OOE B1-2 398.39 398,38 86.51N 73.98E 40,5 113,84 108,99 480,00 480,00 O.OON O.OOE B1-2 479,56 479.54 87.55N 74,27E 40.3 114.81 109.44 500.00 500.00 O.OON O,OOE B1-2 499,29 499.27 87,60N 74,40E 40.3 114.93 110.63 524.93 524,93 0,168 O,11W B1-2 523.71 523,68 87.42N 74.96E -174.4 115,35 111.04 600.00 599,94 2,508 1.75W B1-2 596.18 596,08 86.68N 78.17E -173.1 119,81 115,44 700,00 699,50 9.998 7,OOW B1-2 693,64 693,39 86.99N 83,47E -171.9 132.77 128.25 750.00 749.03 15,61 S 10,93W B1-2 742,98 742.67 87.84N 85,88E -171,8 141.82 137.19 800.00 798.33 22,588 15.43W B1-2 793,51 793,15 88,94N 87.69E -168.0 151,98 147.20 900,00 896,12 40.968 25,24W B1-2 892,13 891,72 89.50N 90.61E -163.7 174.53 169,79 1000.00 992,52 65,198 36,11W B1-2 928,00 927.57 89.67N 91,88E -160,6 211.14 206.20 1100,00 1087.16 95,188 47.98W B1-2 928,00 927.57 89,67N 91,88E -156,6 281,42 276.42 1200.00 1179,68 130,828 60.83W B1-2 928,00 927,57 89,67N 91.88E -151.6 368,10 362,98 1300.00 1269,76 171,988 74.59W B1-2 928.00 927,57 89,67N 91.88E -144.4 461.81 456,54 RECEIVED l~PR ~ ~ 2005 Alaska Oil 8l Cans. Commi$íJìQ!ì , Aot;hon¡ge All data is in Feet unless otherwise stated Coordinates are from 810t and TVD's are from Rig ( Planned Datum 160,3f1 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) Casings Included Prepared by Baker Hughes Incorporated . . UNOCALe UNOCAL M-17 V4, M-17 V4 slot #A 1-9, STEELHEAD Platform CLEARANCE LISTING Page 31 Date Printed: 28-Mar-2005 McArthur River Field, TBU, Cook Inlet, Alaska 0.00 0,00 O,OON O.OOE M-7 0,00 0.00 22.19N 141.65E 81.1 143.38 141.05 16.40 16.40 O.OON O,OOE M-7 16,25 16.25 22,14N 141,68E 81,1 143,40 140,81 100.00 100,00 O,OON O,OOE M-7 99,55 99,54 21.54N 141.96E 81.4 143,59 140.62 200,00 200,00 O,OON O,OOE M-7 199,39 199.38 20,70N 142.52E 81.7 144.02 140.42 300,00 300.00 O.OON O,OOE M-7 301,01 301.00 20,48N 142,53E 81,8 144,00 139.76 400.00 400.00 O,OON O,OOE M-7 401.80 401 ,79 20,59N 141,57E 81,7 143.07 138,20 480,00 480,00 O,OON O,OOE M-7 481.07 481,04 21.51 N 140,59E 81,3 142.23 137.12 500,00 500.00 O.OON O.OOE M-7 500,01 499.98 21,89N 140,40E 81.1 142.09 138.03 600.00 599.94 2.505 1,75W M-7 594,29 594,12 26.53N 141,33E -136.3 146,11 141,88 639.76 639.59 4,885 3.42W M-7 630.20 629,87 29.58N 142.57E -138.0 150.32 146.00 700,00 699,50 9.995 7,OOW M-7 685,39 684.65 35,75N 145,28E -141,1 159.69 155.21 750,00 749.03 15,615 10.93W M-7 728,98 727.72 41,88N 148,06E -143.9 170,40 165,75 800.00 798,33 22.585 15.43W M-7 773,44 771,39 49.41 N 151.53E -143.0 183.80 178.95 900,00 896,12 40,965 25,24W M-7 854,60 850.42 66,13N 159.39E -143,5 218.28 213.29 1000,00 992.52 65.195 36.11 W M-7 933.33 926,34 84,88N 168.47E -145.3 262,21 256,71 1100.00 1087,16 95.185 47,98W M-7 1005.42 995,22 103,78N 178.12E -146,9 314.90 308.96 1200,00 1179,68 130.825 60,83W M-7 1073.48 1059,70 122.88N 188,65E -148,1 375,49 369.05 1300.00 1269.76 171,985 74,59W M-7 1133,33 1115,88 140,61N 199,19E -148.5 443,11 436,15 RECEIVED APR 2 9 2005 Alaska Oil & G~s Cons. CmnmiSSIOTi Anchorage All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig (Planned Datum 160.3ft 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) Casings Included Prepared by Baker Hughes Incorporated . . UNOCALe UNOCAL M-17 V4, M-17 V4 slot #A 1-9, STEELHEAD Platform CLEARANCE LISTING Page 32 Date Printed: 28-Mar-2005 McArthur River Field, TBU, Cook Inlet, Alaska 0,00 0,00 O.OON O.OOE 81-6 0.86 0.11 74.58N 67.67E 42.2 100,70 98,34 100.00 100.00 O.OON O,OOE 81-6 101.15 100,40 74,21 N 67.58E 42,3 100.37 97.40 200.00 200.00 O,OON O,OOE 81-6 201.11 200,36 73.91 N 67,40E 42.4 100.03 96.42 300,00 300,00 O.CON O.OOE 81-6 301 ,13 300.37 73,44N 67,27E 42,5 99.60 95.36 400,00 400.00 O.OON O,OOE 81-6 401,16 400.41 73,10N 67.16E 42,6 99,27 94.40 480.00 480.00 O,OON O,OOE 81-6 481.52 480,77 72.70N 66.91 E 42.6 98.81 93.43 500.00 500,00 O,OON O,OOE 81-6 501,62 500.87 72.70N 66,68E 42.5 98.65 94,26 508,53 508,53 0.02S O,01W 81-6 510,15 509.40 72,72N 66.55E -172.5 98,60 94.19 600.00 599,94 2.50S 1,75W 81-6 601.89 601 ,12 72.76N 65.05E -173.4 100.64 95.91 700.00 699,50 9,99S 7.00W 81-6 701.03 700,25 72.78N 63,51E -174,5 108.74 103.63 738,19 737,35 14,17S 9,92W 81-6 738,90 738.12 72,88N 62.99E -175,0 113,55 108,24 750.00 749.03 15.61 S 10.93W 81-6 750.53 749,75 72.91 N 62.83E -175.2 115.22 109,85 800.00 798,33 22.58S 15,43W 81-6 785,00 784,21 73.12N 62,27E -171,6 124.07 118.61 900,00 896,12 40,96S 25,24W 81-6 785,00 784.21 73,12N 62.27E -165,3 182,20 177.22 1000,00 992.52 65.19S 36.11W 81-6 785.00 784,21 73,12N 62.27E -159.0 268.70 263,81 1100.00 1087,16 95.18S 47.98W 81-6 785.00 784,21 73.12N 62,27E -150.5 363.67 358.74 1200.00 1179,68 130.82S 60,83W 81-6 785,00 784.21 73,12N 62,27E -136.4 461,68 456.61 RECEIVED APR 2 9 2005 Alaska Oil & Gas Cons. Commission Anchorage All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Datum 160.3ft 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) Casings Included Prepared by 8aker Hughes Incorporated . . UNOCAL. UNOCAL M-17 V4, M-17 V4 slot #A 1-9, STEELHEAD Platform CLEARANCE LISTING Page 33 Date Printed: 28-Mar-2005 McArthur River Field, TBU, Cook Inlet, Alaska 0.00 0.00 O,OON O.OOE M-16 0,01 0,01 11,57N 7.65E 33,5 13,87 11.53 100,00 100,00 O,OON O.OOE M-16 100,02 100,02 11.44N 7,60E 33,6 13.73 10.75 135.00 135,00 O.OON O.OOE M-16 135,00 135.00 11.38N 7,58E 33,7 13.68 10.44 200.00 200.00 O.OON O.OOE M-16 199,99 199.99 11,44N 7.58E 33.5 13.73 10,11 300.00 300.00 O,OON O,OOE M-16 300,01 300.01 11,49N 7.48E 33.1 13,71 9.46 400,00 400.00 O,OON O,OOE M-16 399.98 399.98 11,55N 7.50E 33,0 13,78 8.90 459,32 459.32 O,OON O,OOE M-16 459.27 459,27 11,61 N 7.60E 33,2 13,88 8,66 475,72 475,72 O,OON O.OOE M-16 475.67 475,67 11.68N 7.61E 33,1 13,94 8,68 480,00 480,00 O,OON O.OOE M-16 479.88 479,88 11.72N 7.59E 32,9 13.97 8,69 500,00 500,00 O.OON O,OOE M-16 499,88 499,87 12.00N 7,49E 32.0 14,14 9.92 600,00 599,94 2.50S 1,75W M-16 599,15 599,05 15,67N 5,68E 167,2 19.65 15,23 700.00 699.50 9.99S 7,OOW M-16 695,58 694.75 25,86N O,43E 156.2 36.92 32.21 750.00 749.03 15,61 S 10.93W M-16 741,77 740.18 33,56N 2,90W 153,3 50,60 45,71 800.00 798.33 22.58S 15.43W M-16 787,17 784,58 42,57N 5.71W 156,3 67,29 62.20 900.00 896,12 40.96S 25.24W M-16 877.42 872,54 62.42N 9.36W 161.4 107,22 102,00 1000.00 992,52 65,19S 36,11W M-16 958,00 950,53 82.63N 10,05W 165.4 155,86 150.19 1100,00 1087.16 95,18S 47,98W M-16 1030,83 1020.17 103.86N 8,53W 168,5 213.68 207.63 1200,00 1179.68 130,82S 60,83W M-16 1092.47 1078.36 124.02N 5,92W 170,8 279.69 273.23 1300,00 1269.76 171,98S 74.59W M-16 1147,00 1128,79 144.29N 1.65W 172,8 353,86 347.02 1400.00 1357,05 218,50S 89,22W M-16 1191,39 1169,09 162,16N 3.52E 174.6 434,54 427,32 RECEI\/ED APR 2 9 2005 Alaska Oil & Gas COrls. Commission Anchon:¡ge All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig (Planned Datum 160.3ft 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) Casings Included Prepared by Baker Hughes Incorporated . . UNOCALe UNOCAL M-17 V4, M-17 V4 slot #A1-9, STEELHEAD Platform CLEARANCE LISTING Page 34 Date Printed: 28-Mar-2005 McArthur River Field, TBU, Cook Inlet, Alaska 0.00 0,00 O.OON O.OOE M-26 0.00 8.25 88,32N 69,23E 38.1 112.52 110.19 16.40 16.40 O.OON O,OOE M-26 8,15 16,40 88,32N 69.23E 38,1 112,22 109,46 100.00 100.00 O,OON O,OOE M-26 91,75 100,00 88,32N 69.23E 38,1 112.22 108.50 200.00 200,00 O,OON O.OOE M-26 191.75 200,00 88.32N 69,23E 38.1 112.22 107.79 300,00 300,00 O.OON O.OOE M-26 291,75 300.00 88,32N 69,23E 38.1 112,22 107.20 400,00 400,00 O.OON O,OOE M-26 391,75 400,00 88,32N 69.23E 38,1 112,22 106,69 480.00 480.00 O,OON O,OOE M-26 471.75 480,00 88.32N 69.23E 38.1 112.22 106.30 492.13 492,13 O,OON O.OOE M-26 483,88 492.13 88.32N 69,23E 38.1 112.22 106.24 500,00 500,00 O.OON O.OOE M-26 491,75 500.00 88,32N 69.23E 38.1 112.22 107.32 600.00 599.94 2.508 1,75W M-26 591.69 599,94 88.32N 69.23E -177.0 115,27 110.05 656.17 655,93 6,108 4,27W M-26 647.68 655,93 88.32N 69.23E -177.1 119.65 114.24 700.00 699,50 9,998 7.00W M-26 691.25 699.50 88.32N 69,23E -177.2 124.41 118.86 750,00 749,03 15.618 10,93W M-26 740,78 749.03 88.32N 69,23E -177,3 131,25 125.54 800,00 798,33 22,588 15.43W M-26 790,33 798.58 88,34N 69,18E -173.6 139,50 133,57 900.00 896.12 40,968 25.24W M-26 890.62 898,86 87.98N 68.67E -169.6 159,54 153.48 1000,00 992.52 65.198 36.11W M-26 983,62 991,85 86.93N 68,69E -167.7 184.73 178.13 1100.00 1087,16 95.188 47,98W M-26 1072,25 1080.46 88.43N 68,40E -167,3 217.49 210.78 1200.00 1179,68 130.828 60,83W M-26 1158.93 1167,04 92,61N 68,1 DE -167.9 258,27 251.38 1300,00 1269.76 171.988 74.59W M-26 1234,28 1242.16 98.51 N 68.18E -168.3 307,10 299,91 1400,00 1357.05 218,508 89,22W M-26 1304,62 1312.05 106,27N 69,52E -168.7 364.27 356.68 1500.00 1441,22 270.208 104.67W M-26 1367.61 1374.35 115.41N 71,09E -168,9 429.03 420.97 1600.00 1521.96 326.918 120,87W M-26 1423.07 1428.93 125.13N 72,78E -168,8 500,49 492.20 RECEIVED APR 2 9 2005 Alaska Oil & Gas Cons. Ctlf()JJ~~ßjºn Anchorage All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Datum 160,3ft 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 OJ Casings Included Prepared by Baker Hughes Incorporated . . UMOCALe UNOCAL M-17 V4, M-17 V4 slot #A 1-9, STEELHEAD Platform CLEARANCE LISTING Page 35 Date Printed: 28-Mar-2005 McArthur River Field, TBU, Cook Inlet, Alaska 0.00 0,00 O,OON O.OOE M-32 0,25 0,25 83,35N 71,98E 40.8 110.13 107.78 100.00 100.00 O.OON O,OOE M-32 99.82 99,82 83.19N 71,92E 40.8 109,97 107,00 200,00 200,00 O,OON O,OOE M-32 200.14 200,14 82,94N 72,10E 41,0 109,90 106.30 300.00 300.00 O,OON O,OOE M-32 300,52 300.52 82,63N 72,19E 41.1 109.72 105,49 400,00 400,00 O.OON O.OOE M-32 401.20 401,19 81,33N 72.79E 41,8 109,16 104.45 480,00 480.00 O,OON O,OOE M-32 481.83 481.79 79,33N 73,29E 42.7 108.02 103.05 490.96 490.96 O.OON O,OOE M-32 491,00 490,96 79.12N 73.32E 42,8 107,87 102.85 500,00 500,00 O,OON O.OOE M-32 500.72 500,67 78,98N 73.35E 42,9 107.79 103.80 508.53 508.53 0,025 O,01W M-32 509,25 509.20 78.88N 73,37E -172.1 107.75 103,73 600,00 599,94 2.505 1,75W M-32 600,27 600,22 78,05N 73.70E -171.9 110,37 105.90 672.57 672.25 7.445 5.21W M-32 672.96 672.90 77.44N 73,93E -172,0 116.06 111.20 700.00 699.50 9.995 7,OOW M-32 700,56 700.50 77.06N 74.05E -172,0 118.95 114.02 750,00 749,03 15.615 10,93W M-32 749;92 749,86 76.23N 74.41 E -172,0 125.37 120.32 800.00 798.33 22,585 15.43W M-32 799,00 798.93 75.54N 74,85E -168,2 133.34 128,02 900,00 896,12 40,965 25.24W M-32 897.13 897,05 74,19N 75.55E -164.3 153,04 147.54 1000.00 992,52 65.195 36,11W M-32 993,11 993,02 73,27N 76,10E -163,0 178.22 172.44 1100,00 1087.16 95,185 47,98W M-32 1091.92 1091,82 71.85N 75.97E -163,2 208.05 202,21 1200.00 1179,68 130,825 60,83W M-32 1187,12 1186.98 69,15N 75,69E -163.6 242.23 236.25 1300,00 1269.76 171.985 74.59W M-32 1282.57 1282,33 64.88N 75,56E -164,2 280,72 274.52 1400.00 1357,05 218,505 89,22W M-32 1371,03 1370,69 60,56N 75,24E -164.8 324.20 317.82 1500,00 1441.22 270,205 104,67W M-32 1456.51 1456.08 56.78N 74,89E -165,3 373.34 366,73 1600.00 1521.96 326.915 120.87W M-32 1536.02 1535.54 53.82N 74.42E -165.9 428,10 421.51 1700.00 1598.97 388,395 137,76W M-32 1605,43 1604.92 52.22N 74,15E -166,2 488.96 482,13 RECEIVED APR 2 9 2005 Alaska Oil & Ga~ Cons. Commission Anchorage All data is in Feet unl,sss otherwise stated Coordinates are from 510t and TVO's are from Rig ( Planned Datum 160.3ft 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) Casings Included Prepared by Baker Hughes Incorporated . . UNOCALe UNOCAL M-17 V4, M-17 V4 slot #A 1-9, STEELHEAD Platform CLEARANCE LISTING Page 36 Date Printed: 28-Mar-2005 McArthur River Field, TBU, Cook Inlet, Alaska 0,00 0.00 O,OON O,OOE M-32 0,25 0.25 83,35N 71.98E 40,8 110,13 107.78 100.00 100,00 O,OON O,OOE M-32 99,82 99,82 83.19N 71.92E 40,8 109,97 107.00 200.00 200,00 O,OON O,OOE M-32 200.14 200,14 82.94N 72.10E 41,0 109,90 106,30 300,00 300,00 O,OON O.OOE M-32 300.52 300,52 82.63N 72.19E 41.1 109.72 105,49 400,00 400,00 O,OON O.OOE M-32 401.20 401,19 81.33N 72.79E 41,8 109,16 104.45 480,00 480,00 O,OON O,OOE M-32 481.83 481,79 79.33N 73.29E 42,7 108.02 103,05 490,96 490,96 O.OON O.OOE M-32 491,00 490.96 79.12N 73,32E 42.8 107.87 102.85 500,00 500.00 O.OON O.OOE M-32 500,72 500.67 78.98N 73.35E 42.9 107.79 103.80 508.53 508.53 0.02S O,01W M-32 509,25 509.20 78.88N 73,37E -172,1 107.75 103.73 600.00 599.94 2.50S 1,75W M-32 600,27 600.22 78,05N 73,70E -171,9 110.37 105.90 672.57 672.25 7.44S 5,21W M-32 672,96 672.90 77.44N 73.93E -172.0 116.06 111.20 700.00 699,50 9,99S 7,OOW M-32 700.56 700,50 77,06N 74.05E -172,0 118,95 114.02 750,00 749,03 15.61S 10.93W M-32 749.92 749,86 76.23N 74.41E -172.0 125,37 120,32 800.00 798,33 22.58S 15,43W M-32 799.00 798,93 75,54N 74.85E -168.2 133.34 128.02 900,00 896,12 40.96S 25,24W M-32 897,13 897,05 74.19N 75.55E -164.3 153.04 147,54 1000.00 992,52 65.19S 36,11W M-32 993,11 993,02 73.27N 76,10E -163.0 178.22 172.44 1100.00 1087.16 95,18S 47,98W M-32 1091.92 1091.82 71.85N 75,97E -163.2 208.05 202.21 1200.00 1179,68 130.82S 60,83W M-32 1187.12 1186.98 69.15N 75,69E -163,6 242.23 236.25 1300,00 1269,76 171.98S 74,59W M-32 1282.57 1282.33 64,88N 75,56E -164,2 280.72 274.52 1400,00 1357.05 218.50S 89,22W M-32 1371.03 1370.69 60.56N 75,24E -164,8 324.20 317.82 1500,00 1441.22 270,20S 104,67W M-32 1456.51 1456.08 56,78N 74.89E -165,3 373,34 366.73 1600,00 1521.96 326,91 S 120,87W M-32 1536,02 1535.54 53,82N 74.42E -165.9 428,10 421.51 1700.00 1598,97 388,39S 137.76W M-32 1605,43 1604,92 52,22N 74.15E -166.2 488.96 482,13 RECEIVED APR 2 9 2005 Alaska Oil & Gas Cons. Comm;ssìon Anchorage All data is in Feet unless othe/Wise stated Coordinates are from Slot and TVD's are from Rig ( Planned Datum 160.3ft 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) Casings Included Prepared by Baker Hughes Incorporated . . UNOCALe UNOCAL M-17 V4, M-17 V4 slot #A1-9, STEELHEAD Platform CLEARANCE LISTING Page 37 Date Printed: 28-Mar-2005 McArthur River Field, TBU, Cook Inlet, Alaska 0.00 0,00 O.OON O.OOE M-32 0.25 0.25 83,35N 71.98E 40.8 110.13 107.78 100.00 100.00 O.OON O,OOE M-32 99,82 99.82 83,19N 71.92E 40.8 109,97 107.00 200.00 200.00 O.OON O,OOE M-32 200.14 200,14 82,94N 72.10E 41,0 109,90 106.30 300.00 300.00 O,OON O,OOE M-32 300,52 300,52 82,63N 72.19E 41,1 109,72 1 05.49 400.00 400.00 O,OON O,OOE M-32 401.20 401,19 81.33N 72.79E 41,8 109,16 104,45 480.00 480,00 O,OON O,OOE M-32 481.83 481,79 79.33N 73.29E 42,7 108,02 103,05 490.96 490,96 O,OON O,OOE M-32 491.00 490,96 79.12N 73.32E 42,8 107.87 102,85 500,00 500,00 O,OON O,OOE M-32 500.72 500,67 78.98N 73.35E 42,9 107,79 103,80 508.53 508,53 0,028 O,01W M-32 509.25 509,20 78.88N 73,37E -172.1 107.75 103,73 600,00 599,94 2,50S 1,75W M-32 600,27 600,22 78.05N 73,70E -171.9 110.37 105.90 672.57 672,25 7.448 5.21W M-32 672.96 672.90 77.44N 73,93E -172.0 116.06 111,20 700,00 699,50 9,998 7.00W M-32 700,56 700.50 77.06N 74,05E -172.0 118.95 114.02 750,00 749,03 15,618 10,93W M-32 749,92 749.86 76.23N 74,41E -172.0 125.37 120.32 800,00 798,33 22.588 15,43W M-32 799,00 798.93 75.54N 74,85E -168,2 133.34 128.02 900,00 896,12 40,968 25,24W M-32 897,13 897.05 74.19N 75,55E -164,3 153.04 147.54 1000.00 992.52 65,198 36.11W M-32 993,11 993.02 73,27N 76,10E -163.0 178.22 172.44 1100,00 1087.16 95,188 47,98W M-32 1091.92 1091.82 71,85N 75,97E -163,2 208,05 202.21 1200,00 1179.68 130.828 60.83W M-32 1187.12 1186.98 69,15N 75.69E -163.6 242,23 236,25 1300,00 1269.76 171.988 74,59W M-32 1282.57 1282,33 64,88N 75.56E -164,2 280,72 274.52 1400,00 1357.05 218.508 89,22W M-32 1371.03 1370.69 60,56N 75,24E -164.8 324.20 317,82 1500,00 1441,22 270.208 104,67W M-32 1456.51 1456.08 56,78N 74,89E -165,3 373,34 366.73 1600,00 1521.96 326.918 120,87W M-32 1536.02 1535.54 53,82N 74.42E -165,9 428,10 421.51 1700,00 1598.97 388.398 137,76W M-32 1605.43 1604.92 52,22N 74,15E -166,2 488,96 482.13 RECEI\/ED APR 2 9 2005 Alaska Oil & Al1ctHJr~,g¡¡ All data is in Feet unless otherwise stated Coordinates are from 810t and TVD's are from Rig ( Planned Datum 160.3ft 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) Casings Included PrepareØ ay Baker Hughes JncorpQra~ed . . UNOCALe UNOCAL M-17 V4, M-17 V4 slot #A 1-9, STEELHEAD Platform CLEARANCE LISTING Page 38 Date Printed: 28-Mar-2005 McArthur River Field, TBU, Cook Inlet, Alaska 0,00 0.00 O.OON O,OOE M-32 0,25 0,25 83,35N 71.98E 40,8 110,13 107,78 100.00 100.00 O.OON O,OOE M-32 99,82 99.82 83,19N 71.92E 40,8 109,97 107,00 200.00 200.00 O.OON O,OOE M-32 200,14 200.14 82,94N 72,10E 41,0 109,90 106.30 300,00 300.00 O.OON O.OOE M-32 300,52 300.52 82,63N 72.19E 41,1 109,72 1 05.49 400,00 400,00 O.OON O.OOE M-32 401,20 401.19 81.33N 72,79E 41.8 109.16 104.45 480,00 480,00 O.OON O.OOE M-32 481,83 481.79 79.33N 73,29E 42.7 108.02 103.05 490,96 490,96 O,OON O.OOE M-32 491,00 490,96 79.12N 73.32E 42,8 107.87 102.85 500.00 500,00 O,OON O.OOE M-32 500.72 500,67 78.98N 73,35E 42.9 107.79 103.80 508.53 508.53 0,028 O,01W M-32 509.25 509,20 78,88N 73.37E -172.1 107.75 103.73 600.00 599.94 2,508 1.75W M-32 600.27 600,22 78.05N 73.70E -171.9 110,37 105.90 672.57 672.25 7,448 5,21W M-32 672,96 672,90 77.44N 73.93E -172.0 116,06 111,20 700.00 699.50 9.998 7,OOW M-32 700.56 700,50 77.06N 74.05E -172.0 118,95 114,02 750.00 749.03 15.61 S 10.93W M-32 749,92 749,86 76,23N 74.41E -172,0 125,37 120.32 800.00 798.33 22.588 15.43W M-32 799,00 798.93 75,54N 74.85E -168,2 133,34 128.02 900,00 896.12 40,968 25.24W M-32 897,13 897.05 74,19N 75,55E -164.3 153.04 147.54 1000,00 992.52 65,198 36,11W M-32 993.11 993.02 73,27N 76,10E -163.0 178.22 172.44 1100.00 1087,16 95,188 47,98W M-32 1091.92 1091.82 71.85N 75,97E -163,2 208.05 202.21 1200.00 1179,68 130.825 60,83W M-32 1187.12 1186.98 69.15N 75,69E -163,6 242.23 236.25 1300.00 1269,76 171,985 74.59W M-32 1282,57 1282.33 64.88N 75,56E -164,2 280.72 274.52 1400.00 1357,05 218,50S 89,22W M-32 1371,03 1370,69 60.56N 75,24E -164.8 324.20 317.82 1500,00 1441.22 270,205 104,67W M-32 1456,51 1456.08 56.78N 74.89E -165.3 373.34 366,73 1600,00 1521.96 326,915 120,87W M-32 1536,02 1535,54 53.82N 74.42E -165,9 428.10 421,51 1700,00 1598.97 388,395 137,76W M-32 1605,43 1604,92 52.22N 74.15E -166,2 488,96 482,13 RECEI\/ED APR 2 9 2005 Alaska Oil & Gas Cons. l.ûn¡¡¡ïl:;SWf¡ Anchon¡ge All data is in Feet unless otherwise stated Coordinates are from 510t and TVO's are from Rig (Planned Datum 160.3ft 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) Casings Included Prepared by Baker Hughes Incorporated . . UNOCA'" UNOCAL M-17 V4, M-17 V4 slot #A1-9, STEELHEAD Platform CLEARANCE LISTING Page 39 Date Printed: 28-Mar-2005 McArthur River Field, TBU, Cook Inlet, Alaska 0.00 0,00 O,OON O,OOE M-32 0,25 0,25 83.35N 71.98E 40,8 110.13 107,78 100,00 100,00 O.OON O,OOE M-32 99.82 99,82 83.19N 71,92E 40.8 109.97 107.00 200,00 200.00 O.OON O.OOE M-32 200,14 200.14 82.94N 72,10E 41.0 109.90 106.30 300.00 300.00 O.OON O,OOE M-32 300.52 300,52 82,63N 72,19E 41,1 109.72 105.49 400.00 400.00 O,OON O,OOE M-32 401,20 401 ,19 81,33N 72.79E 41,8 109,16 104.45 480,00 480,00 O,OON O,OOE M-32 481.83 481 ,79 79.33N 73.29E 42,7 108,02 103,05 490,96 490,96 O,OON O.OOE M-32 491,00 490.96 79.12N 73,32E 42.8 107.87 102.85 500,00 500.00 O.OON O.OOE M-32 500,72 500.67 78.98N 73,35E 42.9 107.79 103.80 508.53 508.53 0.025 O,01W M-32 509,25 509,20 78,88N 73,37E -172,1 107.75 103.73 600.00 599.94 2.505 1,75W M-32 600,27 600,22 78,05N 73.70E -171.9 110,37 105,90 672.57 672.25 7,445 5,21W M-32 672,96 672,90 77.44N 73.93E -172.0 116,06 111 ,20 700,00 699,50 9,995 7.00W M-32 700.56 700,50 77,06N 74.05E -172.0 118.95 114.02 750,00 749,03 15,615 10,93W M-32 749,92 749,86 76.23N 74.41 E -172.0 125,37 120.32 800,00 798,33 22,585 15,43W M-32 799,00 798.93 75.54N 74,85E -168,2 133.34 128.02 900,00 896,12 40,965 25.24W M-32 897,13 897.05 74.19N 75,55E -164,3 153.04 147.54 1000,00 992.52 65.195 36.11 W M-32 993.11 993.02 73,27N 76.10E -163.0 178,22 172. 44 1100.00 1087.16 95.185 47,98W M-32 1091,92 1091,82 71,85N 75.97E -163.2 208,05 202,21 1200.00 1179,68 130,825 60,83W M-32 1187,12 1186,98 69.15N 75.69E -163.6 242.23 236,25 1300.00 1269,76 171.985 74,59W M-32 1282,57 1282,33 64.88N 75,56E -164.2 280.72 274,52 1400.00 1357.05 218.505 89,22W M-32 1371.03 1370,69 60.56N 75,24E -164,8 324.20 317.82 1500,00 1441,22 270.205 104,67W M-32 1456.51 1456.08 56.78N 74,89E -165,3 373.34 366.73 1600,00 1521.96 326.91 S 120,87W M-32 1536,02 1535.54 53,82N 74,42E -165,9 428,10 421.51 1700,00 1598.97 388,395 137,76W M-32 1605,43 1604,92 52,22N 74.15E -166,2 488,96 482.13 RECEIVED APR 2 9 2005 Alaska Oil & Gas Cons. Anchorage All data is in Feet unless otherwise stated Coordinates are from 510t and TVO's are from Rig ( Planned Datum 160,3ft 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 (1 D) Casings Included Prepared by Saker Hughes Incorporated . . UROCAL. UNOCAL M-17 V4, M-17 V4 slot #A 1-9, STEELHEAD Platform CLEARANCE LISTING Page 40 Date Printed: 28-Mar-2005 McArthur River Field, TBU, Cook Inlet, Alaska 0,00 0.00 O.OON O,OOE M-32 0,25 0.25 83.35N 71.98E 40,8 110,13 107.78 100.00 100,00 O,OON O,OOE M-32 99,82 99,82 83.19N 71.92E 40,8 109.97 107,00 200.00 200,00 O,OON O,OOE M-32 200.14 200,14 82.94N 72 ,1 OE 41,0 109.90 106.30 300.00 300,00 O,OON O.OOE M-32 300,52 300,52 82.63N 72,19E 41.1 109.72 105.49 400,00 400,00 O.OON O.OOE M-32 401,20 401.19 81.33N 72,79E 41.8 109.16 104.45 480,00 480.00 O.OON O.OOE M-32 481,83 481.79 79,33N 73,29E 42.7 108.02 103.05 490.96 490.96 O.OON O,OOE M-32 491,00 490.96 79,12N 73.32E 42.8 107.87 102.85 500.00 500.00 O.OON O,OOE M-32 500.72 500,67 78,98N 73.35E 42,9 107,79 103,80 508.53 508.53 0,028 O,01W M-32 509.25 509,20 78.88N 73.37E -172.1 107,75 103,73 600.00 599.94 2,508 1,75W M-32 600,27 600,22 78.05N 73,70E -171.9 110.37 105,90 672,57 672,25 7.448 5.21W M-32 672,96 672,90 77.44N 73,93E -172.0 116.06 111.20 700,00 699,50 9.998 7,OOW M-32 700,56 700.50 77.06N 74,05E -172,0 118.95 114.02 750,00 749.03 15,61 S 10,93W M-32 749,92 749.86 76.23N 74.41 E -172,0 125.37 120.32 800,00 798.33 22,588 15.43W M-32 799,00 798.93 75,54N 74.85E -168.2 133,34 128.02 900,00 896.12 40,968 25.24W M-32 897.13 897,05 74,19N 75.55E -164.3 153,04 147.54 1000,00 992.52 65.198 36.11W M-32 993.11 993,02 73,27N 76.10E -163.0 178,22 172,44 1100,00 1087,16 95.188 47.98W M-32 1091,92 1091,82 71.85N 75.97E -163.2 208.05 202,21 1200.00 1179,68 130,828 60,83W M-32 1187,12 1186.98 69.15N 75.69E -163,6 242.23 236,25 1300.00 1269,76 171,988 74,59W M-32 1282.57 1282.33 64.88N 75,56E -164,2 280.72 274.52 1400.00 1357,05 218.508 89,22W M-32 1371.03 1370.69 60.56N 75,24E -164,8 324.20 317.82 1500.00 1441,22 270.208 104,67W M-32 1456.51 1456.08 56.78N 74,89E -165,3 373.34 366.73 1600.00 1521,96 326.918 120,87W M-32 1536,02 1535.54 53,82N 74.42E -165,9 428.10 421.51 1700.00 1598.97 388.398 137,76W M-32 1605.43 1604.92 52.22N 74,15E -166,2 488,96 482.13 RECEi\/ED APR 2 9 2.D05 ^'aska mj &. . Af!d¡î.ií1:¡ge All data is in Feet unless otherwise stated Coordinates are from 810t and TVD's are from Rig ( Planned Datum 160,3f1 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 OJ Casings Included Prepared by Baker Hughes Incorporated . . UNOCALe UNOCAL M-17 V4, M-17 V4 slot #A1-9, STEELHEAD Platform CLEARANCE LISTING Page 41 Date Printed: 28-Mar-2005 McArthur River Field, TBU, Cook Inlet, Alaska 0.00 0,00 O.OON O.OOE M-1 3.11 0.36 23.39N 146.28E 80.9 148.14 145.73 100.00 100.00 O.OON O,OOE M-1 104.15 101,39 23.00N 145,82E 81.0 147,63 144.64 200.00 200,00 O,OON O,OOE M-1 203.88 201,12 22.20N 145,03E 81,3 146.72 143,10 300,00 300,00 O,OON O.OOE M-1 303,13 300,36 21.62N 144.47E 81.5 146.08 141.83 347,24 347.24 O.OON O.OOE M-1 350,00 347.24 21,58N 144.35E 81.5 145.96 141.39 400.00 400.00 O.OON O,OOE M-1 401.93 399,16 21,82N 144.43E 81,4 146,07 141.20 442.91 442.91 O,OON O.OOE M-1 444.84 442,07 22.12N 144,63E 81,3 146.32 141.16 480,00 480,00 O,OON O.OOE M-1 481,47 478.70 22.35N 144.91 E 81.2 146.63 141.24 500,00 500.00 O.OON O.OOE M-1 501,44 498.67 22,48N 145,07E 81.2 146.80 142.41 600.00 599.94 2.50S 1,75W M-1 601,92 599,15 22,88N 145,78E -134,7 149,70 144.81 700.00 699,50 9,99S 7,OOW M-1 701.19 698,42 23,14N 146,27E -136.9 156,81 151.41 750,00 749,03 15.61S 10,93W M-1 750.17 747.40 23,54N 146.58E -138.6 162.31 156.80 800,00 798,33 22,58S 15,43W M-1 798,81 796,03 24.32N 146.99E -136,6 169.07 163.46 900,00 896,12 40,96S 25,24W M-1 891,25 888.36 28,32N 148,29E -136.4 187,01 181.46 1000,00 992.52 65.19S 36.11 W M-1 979.29 976,03 36,OON 150,24E -139.1 212,69 206,84 1100,00 1087.16 95.18S 47.98W M-1 1061,44 1057.40 46.92N 152,76E -142.6 247.74 241.60 1200.00 1179,68 130.82S 60,83W M-1 1134,60 1129.32 59.97N 155.75E -145,8 292.99 286.44 1300.00 1269,76 171.98S 74,59W M-1 1200.22 1193.23 74,51N 158.99E -148,3 348.10 341.11 1400.00 1357.05 218.50S 89,22W M-1 1257.77 1248.67 89,47N 162.66E -149.9 412.35 404,92 1500,00 1441.22 270,20S 104,67W M-1 1308,45 1296,96 104.40N 166,37E -150,8 484,35 476,50 RECEI\/E APR 2 9 2005 Alaskti Oil & Gas Anchorage All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Datum 160.3ft 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) Casings Included Prepared by Baker Hughes Incorporated . . UNOCALe UNOCAL M-17 V4, M-17 V4 slot #A1-9, STEELHEAD Platform CLEARANCE LISTING Page 42 Date Printed: 28-Mar-2005 McArthur River Field, TBU, Cook Inlet, Alaska 0,00 0.00 O.OON O,OOE M-1 3,11 0,36 23,39N 146,28E 80,9 148,14 145.73 100.00 100.00 O,OON O,OOE M-1 104.15 101,39 23,OON 145,82E 81,0 147,63 144,64 200.00 200,00 O,OON O,OOE M-1 203.88 201,12 22.20N 145.03E 81,3 146,72 143,10 300.00 300,00 O,OON O,OOE M-1 303.13 300,36 21.62N 144,47E 81,5 146,08 141,83 347.24 347,24 O,OON O.OOE M-1 350.00 347,24 21.58N 144,35E 81,5 145.96 141,39 400,00 400,00 O,OON O.OOE M-1 401.93 399,16 21.82N 144.43E 81.4 146.07 141.20 442.91 442,91 O,OON O.OOE M-1 444.84 442,07 22.12N 144,63E 81,3 146.32 141.16 480,00 480,00 O.OON O.OOE M-1 481.47 478,70 22.35N 144.91 E 81,2 146.63 141.24 500,00 500,00 O.OON O.OOE M-1 501.44 498,67 22.48N 145,07E 81,2 146,80 142.41 600,00 599,94 2,508 1.75W M-1 601.92 599,15 22.88N 145,78E -134.7 149.70 144,81 700,00 699,50 9,998 7.00W M-1 701,19 698.42 23.14N 146,27E -136.9 156.81 151.41 750,00 749,03 15,618 10,93W M-1 750,17 747.40 23.54N 146.58E -138.6 162.31 156.80 800,00 798,33 22,588 15.43W M-1 798,81 796,03 24.32N 146.99E -136.6 169.07 163.46 900,00 896,12 40,968 25,24W M-1 891 ,25 888.36 28.32N 148.29E -136,4 187.01 181.46 1000.00 992,52 65,198 36,11W M-1 979,29 976,03 36.00N 150.24E -139,1 212.69 206.84 1100.00 1087.16 95,188 47,98W M-1 1061.44 1057.40 46.92N 152.76E -142.6 247.74 241.60 1200.00 1179,68 130.828 60,83W M-1 1134.60 1129,32 59.97N 155.75E -145,8 292.99 286.44 1300.00 1269.76 171.988 74,59W M-1 1200.22 1193.23 74.51N 158.99E -148,3 348.10 341.11 1400,00 1357.05 218.508 89,22W M-1 1257.77 1248.67 89.47N 162.66E -149,9 412.35 404.92 1500,00 1441.22 270,208 104,67W M-1 1308.45 1296.96 104.40N 166.37E -150,8 484.35 476.50 RECEI\fED APR 2 9 2.005 t, 1'\:1 0'... c. "fI" LumnU¡¡SlOn A\azlu~ \:\1 <'¿l '\1 ~. Anchorage All data is in Feet unless otherwise stated Coordinates are from 810t and TVO's are from Rig ( Planned Datum 160.3f1 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 (1 D) Casings Included Prepared by Baker Hughes Incorporated RECEIVED APR2 9 2D05 POST THIS NOTICE IN THE DOGHOUS)la~Ka ŒI & .. C~ms, Cormnissioit Anchûrage . M-17 Steel head Summary of DrillinQ Hazards .. . 17-1/2" and 12-1/4" Surface Hole Sections · The shallow gas sands which will be encountered in the surface hole sections had previously been charged up with gas during the M-26 blowout in 1987. Since that time a secondary casing string has been installed in all Steel head wells at roughly 850' MD to allow for nippling up a BOP stack prior to drilling the potentially charged up interval below this shallow casing string. · M-13, M-14 and M-15 are all critical close approach wells. Record annulus pressures on these wells prior to spud and monitor during the drilling of the surface hole. · Special care is required in the following areas: 1. Monitor trip tank on each trip into and out of the hole, 2. Have LCM material onboard and ready for use in the event significant losses occur. 3. Minimize surge and swab pressures while tripping. 4. Review cement spacers and washes to ensure adequate the well is not underbalanced. 8-1/2" Intermediate Hole Section: · Significantly underpressured reservoir sands will be encountered A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate interval. · Loss circulation is considered to be a major risk due to the depleted reservoir sands which will be encountered. Loss circulation materials will be readily available for adding to the mud system should significant losses be encountered. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures · Differential sticking is a considerable risk while drilling these depleted sands. Keep the drillstring moving whenever possible. · Numerous coals will be drilled through. Unocal coal drilling strategy; limiting the amount of coal drilled «10') prior to reaming back will be followed. 6-1/8" Production Hole Section: · Significantly underpressured reservoir sands will be encountered A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the production interval. · Loss circulation is considered to be a major risk. Loss circulation materials will be readily available for adding to the mud system should significant losses be encountered. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures · Differential sticking is a considered a major risk. Keep the drillstring moving whenever possible. HYDROGEN SULFIDE - H2S . Steel head is designated as an H2S drill site. Standard Operating Procedures for H2S precautions should be followed at all times. Version 1.0 Rigsite Hazards and Contingencies . . Note to File Trading Bay Unit M-17 Spacing Exception Determination Recommendation: Spacing Exception Not Needed Rationale: The Grayling Gas Sands are equivalent to the Middle Kenai Gas Pool, as defined in CO 228 and expanded vertically by CO 228.2. Rule 1 of CO 228 establishes 10-acre drilling units for the Middle Kenai Gas Pool at the mid-point of the pool, which is the D-l sand. The clear intent of CO 228 is to establish 10-acre spacing because ofthe lenticular nature ofthe fluvial reservoir sands. The nearest gas well to the proposed TBU M-l7 well is TBU M-2, which is located 1,700' to the southeast (see attached map). As proposed, TBU M-l7 conforms to the lO-acre spacing requirements of CO 228. The spacing exception requested by Unocal is not necessary. Steve Davies Petroleum Geologist Alaska Oil and Gas Conservation Commission May 9, 2005 STEELHEAD M-17 Proposed Producer Grayling Gas Sands 2050690 SFD 6/412006 .. . Unocal Alaska a Union Oil Company of Cal_a 909 West 9th Avenue, PO, Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 Fax (907) 263-7698 ..--/~ - 1 ,- 11~ ;l e6'-f)ft",< UNOCAL8 RECE 0 9 2005 . & Gas Cons. Commission Anchorage Kevin A. Tabler, Manager Land/Government Affairs M . Steve Davies laska Oil and Gas Conservation í;0mmlsslOn ':1 333 West 7th Avenue, Suite 100 íJ h' Anchorage, Alaska 99501 ,\ Ii STEELHEAD PLATFORM PERMIT TO DRILL AND APPLICATION FOR SPACING EXCEPTION M-17 TBU Union Oil C pany of California (Unocal), as Operator of the Trading Bay Unit (TBU) hereby sub its this Application for Spacing Exception to drill the referenced M -17 well in the T . Our anticipated spud date is late May to mid June, 2005. In accordance with 20 AA 25.005 (a), a Permit to Drill and associated filing fees (check number # 2008168) are filed erewith. Additionally, as part of this submittal, Unocal further requests A inistrative Approval for a well spacing exception to Rule 1, pursuant to Rule 3, nservation Order No. 228. The M-17 well will be drilled from a surface location of 1053' FNL, 454' FWL, Section 33, Township 9N - Range 13W SM to a bottomhole location of2270' FSL, 89' FEL, Section 32, Township 9N - Range 13W SM. The top prospective productive interval is situated directly over the bottomhole location of2270' FSL, 89' FEL, Section 32, Township 9N -Range 13W, only shallower in depth. ! In accordance with 20 AAC 25.055 (a) (4), and if the results of the M-17 well are successful, such well will be within 3000' of a well capable of producing from the same " e - pool. The applicable regulations provide in pertinent part, "not more than one well may be drilled to and completed in that pool on any governmental section; a well may not be drilled or completed closer than 3,000 feet to any well drilling to or capable of producing from the same pool." This well location is structurally high on the formation and is a crestal withdrawal based on seismic, dip meter and subsurface data available to Unocal. Additionally, the correlative rights of all affected owners, landowners and operators will be protected by exception approval. The owners, landowners and operators are the same in both leases (ADL's 17594 and 18730) affected by this well proposal and are located within the approved Grayling Gas Sands Participating Area of the TBU. At the date of this mailing, in accordance with 20 AAC 25.055 (d)(1), notice of our intent to drill has been sent by certified mail to all owners, landowners, and operators of all outlying properties within 3,000 feet of the M-17 well. A copy of this application (landowner notice) along with a certified mailing receipt has been attached to this application. Pursuant to 20 AAC 25.055 (d)(2), enclosed is a plat, identified as Exhibit "A", which shows the location of the well for which the exception is sought and all adjoining properties. Also enclosed, Exhibit "A-I" identifies the owners, landowners and operators associated with the affected tract. Pursuant to 20 AAC 25.055 (d)(3), an affidavit is enclosed stating the undersigned is acquainted with the facts and verifying that all facts are true. It is requested that the Commission approve, by Administrative Approval an exception to the statewide spacing regulation for the drilling of the proposed M-17 well. If you require additional information regarding the M-17 well, please contact Mr. Neil Magee drilling engineer at 263-7804, or you may contact the undersigned at 907-263- 7600. Enclosures cc:Moco DNR RECEIVED APR 2 9 2005 Aa$k~ Oil & Gìl$ Cons. Anch\1rsfje e e VERIFICATION OF APPLICATION FOR SPACING EXCEPTION COOK INLET, ALASKA ADL's 17594, 18730 M-17 well TBU I, KEVIN A. TABLER, Manager, Land and Government Affairs, Union Oil Company of California, do hereby verify the following: I am acquainted with the application submitted for the drilling of the M-17 well in the Trading Bay Unit. I have reviewed the application submitted for the exception to 20 AAC 25.055 (a)(4) and all facts therein are true. I have reviewed the plat attached to said application, and it correctly portrays pertinent and required data. DATED at Anchorage, Alaska this 15th day of April, 2005. ~,J èI~ evin A. Tabler Mgr., Land & Govt. Affairs STATE OF ALASKA ) ) ss ) THIRD JUDICIAL DISTRICT SUBSCRIBED TO AND SWORN before me this 15th day of April, 2005. ~\\\\\\IIIIJJIIÛUú ~ /1<.. 8,/: ~ ~ ~~.····"····.1"k ~ ~~/~9-õ;,"'~ ~ ~.:;j ... CP" ,. ...'1- ~ ii "')f:t rt"A. 'OX l ~ S ·NOllU'- . - II \ PUBLIC.f *7== .. ....-~...'.t!!; " .c-'b 14 '.U",' ,;:s"' ú'/;f~töt~~ . "'11I11\ \\\\\~ ~~ N TARYPUBLIC IN AND FOR THE STATE OF ALASKA My Commission expires: ól-I ~ -~ L. , , . EXHIBIT A McArthur River Field Steelhead Platform M-17 Well Proposal 750 375 I o 750 I Feet ADL017594 LEASE ADL-17594 (Section. 32) T9N-R13W ADL-18730 (Section. 33) T9N-R13W e . EXHIBIT "A-I" LANDOWNER OWNER DNR Unoca1 & Moco Division of Oil and Gas 550 West ih Avenue, Suite 800 Anchorage, Alaska 99501-3560 Attn: Carol Lee DNR Unocal & Moco Division of Oil and Gas 550 West ih Avenue, Suite 800 Anchorage, Alaska 99501-3560 Attn: Carol Lee RECEf\/ED APR 2 9 2005 Ala£ka fit OPERATOR Unocal Unocal cr:: a.- 4 Check type of mail or service: Certified COD Delivery Confirmation Express Mail Insured Recorded Delivery (International) Registered Return Receipt for Merchandise Signature Confirmation Stamp Here (II issued as a certificate of mailing, or for additional copies of this bill) and Name and Address of Sender Line Article Number Addressee Name, Street, and PO Address Postage Insured ' Due Sender Value if COD 100 I 03'1o oOOS 588& q61~ J. Brock Riddle Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 2 3 4 . 5 1DO ¡ 03'bo ()OOCj sßí~ 6 7 ,ß~t ~ W .:> 1W 1(.) 12W ce. Ln o o 1~ ~ ~ e 13 § (G ~ CI1 4' 14, 15) ...._"'.,._...._.............."...______........._mm·... Total Number of Pieces Listed by Sender ;;L :t< domestic and registered mail. The maximum indemnity 01 nonnegotiable under Express Mail document reconslruction insurance is $500 limitations for muNiple pieces losl or damages in a single catastrophic occurrence. The maximum Mail merchandise insurance is $500, but optional Express Mail Service merchandise insurance is available up to to some, but not all countries, The maximum indemnity payable is $25,000 for regislered mail. See Domestic Mail S913, and 5921 for limitations of coverage on insured and COD mail. See International Mail Manua/for limitations covera eon internationai mail. S ecial handlin char es a pI ani to Standard Mail A and Standard Mail B) arcel., omplete by Typewriter, Ink, or Ball Point Pen . Total Number of Pieces Received at Post Office PS Form 3877, August 2000 · Unocal 011 & .'Vision Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 ( UNOCAL8 Robert T. Anderson Manager, Lands Alaska Region March 9, 1990 Mr. Chat Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 ( TRADING BAY UNIT State of 'Alaska Revised Conservation Orders Nos. 80 and 228 Dear Mr. Chatterton: Union Oil Company of California (UNOCAL), as Operator of the Trading Bay Unit~ McArthur River Field, and on behalf of the working interest owners~ for purposes of developing the Middle Kenai Gas Pool for production of newly completed zones, requests the following amendments to Conservation Order No~ 80, McArthur River Field rules: Middle . Kenai Gas' Pool Definition. We request that Rule l(b) of Conservation Order 80, as directed by Conservation Order 228, definition of the Middle Kenai Gas Pool (also knoW1 as Grayling Gas" Sands),;~ be amended to group all of the intervals currently believed to be capable of producing gas in a single pool. To achieve this~ Rule l(b) should be amended to read: The Middle Kenai Ga sPool is accumulation of gas common to, and wi th, the accumulation found in the Bay Unit wells between the measured in Well M-l to 8,982' in Well M-14. defined as the \'hich correlates Marathon Trading depths of 1,518' RECEIVED \ MAR - 91qqn Alaska Oil & Gas Cons. commiS$l.QØ. Anchorage · . S7A7E OF A:"ASKA ALASKA OIL AND GAS CO~SERVA7ION CO~~!ISSION 3001 PorcuDine D=ive Anchorage, Alaska 99501-3192 Re: 7HE APPLICATION OF UNION ) OIL COMPANY OF CALIFORNIA ) (Unocal) on behalf of the ) Trading Bay Unit Working ) Interest Owners requesting) amendments to Conservation) Ord€:.;-~R~.. 80 regarding the) Mc,A"rthùrRiver Middle ) KeÎiåì'Gã'sPÕÖI. ) Conservation Order No. 228 McArthur River Field McArthur River Middle Kena.i Gas Pool April 17, 1987 IT APPEARING THAT: 1. Unocal, by letter dated February 16, 1987, requested amendments to Conservation Order No. 80 and the estab- lishment of pool rules to facilitate development of the McArthur River Middle Kenai Gas Pool. 2. Notice of public hearing was published in the Anchorage Daily News on March 19, 1987. C:. , 3. No protests were filed with the Commission. FINDINGS: 1. The Steelhead Platform has been placed on location, and is being prepared to develop the McArthur River Middle Kenai Gas Pool. 2. The proposed redefined McArthur River Middle Kenai Gas Pool consists of non-marine fluvial sands. The verti- cal limits of the pool may be defined in the Trading Bay Unit State G-2 well. .. 3. Top of the P-l sand represents the approximate midpoin~ of the proposed redefined pool. 4. An empirical relationship between well spacing a.nd ultimate recovery cannot be established due to the large vertical section and lenticular nature of the reservoir. 5. Though not quantifiable, ultimate recovery of gas will be enhanced as well density is increased. 6. A vertical differential pressure of as much as 1860 psi may be expected across the McArthur River Middle Kenai Gas Pool. . . Conse~vation O~de~ No. 228 April 17, 1987 Page 2 7. Gas recovery efficiency may be reduced if low pressure and high pressure intervals are in communication through a wellbore. NOW, THREREFORE, IT IS ORDERED THAT Rule l(b) of Conservation Order No. 80 is repealed and reenacted to read: The McArthur River Middle Kenai Gas Pool is defined as the accumulation of gas occurring within an interval that is stratigraphically equivalent to the interval in Tra.ding Bay.: Unit State G-2 between the measured depths of 2762 feet and 6515 feet. IT IS FURTHER ORDERED THAT the rules hereinafter set forth for the development and production from the McArthur River Middle Kenai Gas Pool, as defined above, apply to the following area: Townshiu 8 North, Range 13 West, Seward Meridian ,P/) Lr/t-~, t3'LÎ (j t ,-' Sections 4 through 8: Section 9: Section 16: Sections 17 through 20: Section 29: Section 30: All W~, .1'1E::: 1/ w~1 , All r/ NW3:: NE3::< ToWnship 8 North, Range 14 West, Sewa.rd Meridian Section 1 : All Section 12: E~, NW>;; v Townshiu 9 North, Range 13 West, Seward Meridian . . Section 9: S~ Section 14: SW3:: Sections 15 through 17: All Section 18: S~ Sections 19 through 22: All Section 23: ~ Section 26: W~ f Sections 27 through 34: Aile Sect:"on 35: NW>;; Townshiu 9 North, Range 14 West, Seward Meridian Section 24: E% ~ Section 25 : E~ . V Section 36: NE3:: Conservation ~er No. 228 Apri.l 17, 1987 Page 3 . Rule 1 Well Spacing Tèn Riff D-1 1J.B::f;~.s · are establ:i.SnèdfÒtt.Iie'Mê.$.:ttnur Pôòl"at the point of penetration of the Rule 2 Production Intervals Production intervals of the McArthur River Middle Kenai Gas Pool with more than 1000 feet (true vertical) be~Neen the bottom and top perforations shall not be in communication within the same wellbore. Rule 3 Administrative Approval Upon request, the Commission may administratively amend this order as long as the operator demonstrates to the Commission's satisfaction that sound engineering practices are maintained and the amendment will not result in physical waste. DONE at Anchorage, Alaska, and dated April 17, 1987. Commission Lonni~~.~~70~r Alaska Oil and Gas Conservation Commission It! v. W. W. Barnwell, Commissioner Alaska Oil and Gas Conservation Commission · . ~~&~Œ @W &~&~~& ALASKA OIL AND GAS CONSERVATION CO~I~IISSION STEVE COWPER, GOVERNOR April 2, 1990 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501·3192 PHONE: (907) 279-1433 Telecopy No. (907)276-7542 ADM I N I S T RAT I V E A P PRO V A L N O. 228.2 Re: Vertical expansion of the McArthur River Middle Kenai Gas Pool. Robert T. Anderson Manager, Lands Alaska Region Unocal Corporation P. O. Box 190247 Anchorage, AK 99519-0247 Dear Hr. Anderson: We have received Unocal's application of March 9, 1990 for vertical expansion of the McArthur River Middle Kenai Gas Pool. On behalf of Unocal and the Working Interest Owners of the Trading Bay Unit you have requested an amendment to Conservation Order (C.O.) 228. Supplementary data was submitted to the Commission on March 30, 1990 and the issue discussed with unit representatives at that time. The Commission has reviewed your request and determined that sound engineering practices will be maintained and the amendment will not result in physical waste. Therefore the Commission hereby repeals Rule l(b) of C.O. 80 as amended by C.O. 228 and reenacts the rule to read: Rule 1. Definition of Pools. (b) The McArthur River Middle Kenai Gas Pool is defined as the ~ccumulation of gas occurring within an interval that is stratigraphically equivalent to the interval in Trading Bay Unit K-2 between the measured depths of 1,780 feet and 10,128 feet. rY?lP- '2:4rCh~~ Chairman BY ORDER OF THE COMMISSION dlf/3.AA228 CITIBANK DELAWARE A Subsidiary of Citicorp ONE PENN'S WAY NEW CASTLE, DE 19720 62·20 3i1 Union Oil Company of California Accounts Payable Field Disbursing 2008168 ,~ UNOCAL-ttti Pay One Hundred Dollars And 00 Cents************************************************************* Date Check Amount . To the order of STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE, AK 99501 United States 13-APR-05 Void after six months from above date, *********100.00 ~ __ ~ D.A. PAGE APR 1 J 2005 /II 2008 . b8111 1:031. .00 20 g.: 31 g . . 8 . 31 ? III ,_. ...~.._ ___ "0 FCS l¡jOU!:~icS CCNT~CT LCC,\T;:~;\! "'.i'~::~E :;"J\'C:CE:'} ·'''j~ME;U2\li :Të: VENDOR NO, DATE CHECK NO. ~. I I I I i 1031548 04-13-05 I 2008168 i DATE INVOICE/CREDIT MEMO NO. VOUCHER NO, GROSS DISCOUNT NET 04-13-05 M17DRILLPERMIT 10316970 I 100.00 100.00 I I I FORM 4-28181 (REV, 11-95) PRINTED IN U,SA I TOTAL ~ I I DET.¿,CH STUB 8E;=CF~E DE?OSITi;\¡C: c:-~¿c:'< 100.00 I I 100.00 . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME .-r B a /11 r- /7 PTD# '2ðs--ob9 CHECK WHAT APPLIES ADD-ONS (OPTIONS MULTI LATERAL "CLUE" (If API number last two (2) digits are between 60-69) The permit is for a new wellbore segment of existing well _, Permit No, API No. Production should continue to be reported as a function of the original API number stated above. PILOT (PH) HOLE In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce/inject is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing ception tha may- oc . tt-¿ , II dry ditch sample sets s bmitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 04101/05 C\j ody\trans mittaL checklist ~. J-- ~I/J 4-j~ /'~ ·~-r d- ~=(f:.fgÞ . ,. 1_ / t "bVi-:tr ~ ~~:"cA~~~:4 </Y!o(/ ~~ rf~, ~A'(1 ~ ~+,~L/¿7/~ ~ ~W!. ~/ ~~j~. "ç ç_ (0" o o Disposal Well bore seg Annular On Program DEV On/Off Shore 12DZQ Unit TRADING BAY UNIT M-17 _a2 Well Name: PENQ GeoArea DEV 17'5M. top prod interyal & rD in ADL 1873Q, surfac_e locatjo_n In ADL CorreçtjoJlmade 10_ 40j 5_20550, governed_ byCQ 22K - MCARTHUR RIYER, MIDKEN,ð.1 GAS . Ye$ No Y~$ Y_e$ Y~$ Y~$ Ye$ Y~$ Ye$ _Y_es Y~$ No_ Yes _NA NA _NA Y~s nitial ClassfType 520550 MCARTHUR RIVER, MIDKENAI GAS AUFQRNIA P~rmit fee atlacheJ:l _Leas~number jipprO':1riate_ boundjiry _ n_ame _and olJ.mb~r locat~d In_a d_efineJ:lPOQI located pwper _distance_ from driJIing unit located proper distance_ from otoer welJs S_ufficient ~ Ifdeviatec in drilJiog lJ.nit incJuded ",creage _ayailable js weJlbore plat Operator only affected party _Oper_ator oas_appropriateJ~ond inJorce _Unique wel WEd Well Well co_n$ervation order admini$trathle approval P~rmit can be iS$lJ.ed )\/jtooul Permit can be iS$lJ.ed )\/jtoout in_ cOO1m~nts) (For Can permit Well located within area an_d_strata authorized by_Injection Order # (put 10# 15-day wait be approved before se/'Vice well Qn!y) reyiew jd~ntified (For servjc~ well only) J:luratio_n of pre-production I~ss than:3 lJlontos_ (For AJI weHs_ witþin J l43uile _area_of Pre-produced injector 2 3 4 5 6 7 8 9 Administration Date Appr SFD 5/9/2005 drilled frQm exjsting platform Wel M aqllifeI$ eX~01pted,4P _CFR_147.1 Q2_ (b~(2)(iv) ConductQrand surf_ace ca$ing to_b~cementedto surfaçe. _Ye$ _NA Yes Y~s Ye$ Y~s Yes ACMP F:indjng _of Con$i$tency h_a$ beeJl Jssued_ for_ tbi$ pr_oiect _C_ooductor _S_urfacecasingpJotects a\ strin-9_pJQvided 18 19 20 Engineering _known USDWs I~'ð n" _cond_uctor_ tie-in tring to_Sllrf C$g_ & su_rf_C$g _CMT vol adeQu_ale_ to circul~.v~,. _CMT v_ol adeQuate_ to CMTwilJ coyer_a]l koownpro_ductiye bQrizQn_s Rig located On off$oore plç¡tfoJIJl. Rig has steel pits,DJillil1g wastesJQ be discharged io accord with NPDES. Gyros likely to_ 120Q' Close approacoe_s Jdentjfied. I?ro~ilJllty: anjil!Ysis perf_orme_d . 1:34~'_ tvd ss, 8,4 ppg @RKB, _MW pljilnned _-9.2 ppg. 3QQO_p$iBQP testproposed._ _NA_ _Y~s Yes Yes Y~s Y~s Y_es Y~s No NA C,_T4 B_&permafr_o$t C_asil1g designs adequate for be~11 ç¡PPJQved AJ:lequatetanhge_oJ re_serye pit JtaJe-J:lrilt has_a_ tO~403 fQr jilbandonment AJ:lequate )~e!lbore sep"lratjoJl_proposed t me!9t r!9gulations_ Jtdjverter Jeqllired, does Maxjmum exp!9cted formation pressur~_9AEMW @ psi M,ð.Sr: calcu!ated_at 242j WOJk will occ_ur withoutoperation _shlJ.tdoWJl Is presence_ of H2S gas_ prOQab1e Mecoa_nicç¡l_coodjt[onof listadequate BOPE$,_do _they meet r!9gulatioo _BOPE_pres$ rating appropriate; Jesl to (puJ PSig in_comments) _ChokemanifQld complies w/Al?t RF'-53 (May 84) _DJilling fIujd_pJQgram schematic & eqllip Date 5/6/2005 Appr TEM 1-125 is notrep-ortect in G_G_S, Hjg i& eQujpped wilh_ s_el1sors_ and _alarms-. NQ signJf¡cç¡nt Ii2S jll produçtion Jrom_GraYJing Gas_ Sands. Sha!lQW ov_erpressure eXP!9ctect in SZ1 t int~rva'-at WjlLbedrílled wito 9.4 ppg muct.Remajndetof wel Y~s Y~s _NA _NA NA well$ within ,ð.OR verifiect (for_ service welJ only) can be tSSlJ.ed wlo_ hydr:ogellsulfide mesS_ures Permit _D_ata_pr~seoted Qn_ pote_ntial oveJpreSsur!9 _Zone$ 35 36 37 38 39 Geology 1\ID~ Mitigation di$cussedjn Dr:illing _H_azards_ write-up D1~at -58851\1Q, whiçh i$ :34~' is underpre_sSlJ.red untit Date 5/5/2005 Appr SFD expected to be 8.6 ppg EMW, _S~tS01icanalysjs Qf sbaJlow gas_zones_ _S~ç¡bed conditiol1 $urvey _(if Qf{-sh_ore) Date SPACING EXCEPTION NOT NEEDED: the Grayling Gas Sands are equivalent to the Middle Kenai Gas Pool, as defined in CO 228 and expanded vertically by CO 228.2. Rule 1 of CO 228 established 10-acre drilling units for the Middle Kenai Gas ~ Pool at the mid-point of the pool, which is the D-1 sand. The clear intent of the order is to establish 10-acre spacing because /1' /. . of the lenticular nature of the fluvial reservoir sands. The nearest gas well is TBU M-2, which is located 1,700' SE. This well ~ Ø~~ms to the 10-acre sDacino reouirements of CO 228_ CQnta_ct na!nelphoneJorwee~ly progress_reports [exploratory _only] ~ Date :5 -( () ~o5" Engineering Commissioner: ~,.~. Date: Geologic Commissioner: