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Home My WebLink About197-028Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / ~' 7 -~,,~. ~ File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Mn ~¢;/~/,'(~ ~--~/O('- /"~/I0'/-~2..~ I-I GraYScale, halftones, pictures, graphs, charts - Pages: Poor Quality Original- Pages: Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type .OVERSIZED .Logs of vadous kinds Other COMMENTS: Scanned by: ~,~w~, Mitdmd-Daretha ~Loweli Date.: --~/// n TO RE-SCAN Notes: Re-Scanned by: ~verb, M~ Darelha Nathan Lowell Date: /si ON OR BEFORE ANL ARY 03 2001 W C:LORB~ ~L~vi.DOC Memorandum To: Re: State of Alaska Oil and Gas Conservation Commission Well File: 5/"~ _ .L.~b~ DATE Cancelled or Expired Permit Action EXAMPLE: Point Mclntyre P2-36AXX API# 029-22801-95 This memo will remain at the from of the subject well ~e. Our adopted conventions for assigning APl numbers, permit numbers and well names did not specifically address expired or cancelled permits. This omission has caused some inconsistencies the treatment of these kinds of applications for permit to ddll. Operators have asked us to adopt formal procedures for this class of permit application in order to prevent future database disparities. If a permit expires or is cancelled by an operator, the permit number of the subject permit will remair, unchanged. The APl number and in some instances the well name reflect the number of preexistin.( reddlis and or muitilaterais in a well. In order to prevent confusing a cancelled or expired permit with an active well or multilateral these case sensitive well identifiers will be changed for expired and cancelled applications for permits to ddil. The AP! number for this cancelled or expired permit is modified so the eleven and twelfth digits is 9[ The well name for a cancelled or expired permit is modified with an appended xx. These procedures are an addendum to the APl numbering methods descnbed in AOGCC staff memorandum "Multi-lateral (wettbore segment) Ddlling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician To: From; Subject: David W, Johnston David Nim$ Eiger #1 Exploration Well Status _~hared ~;~,ervices Date: 3/4/97 There are no intentions to drill the Eiger #1 exploration well (drilling permit #97- 28) from the Pete's Wicked #1 ice pad, Both the conductor and cellar have been plug and abandon, If you have any questions, please contaot Floyd Hernandez at 564-5960, ;v¢./:\R 0 4 1997 Gas Cons. Co,~missio~ Anchocage BP EXp LO_FL-.ATION BP Explomtlon (Alaska) Ino. PO Box 1966.12 Anchorage, Alaska 99519-6612 TELECOPY COMMUNICATIONS CENTER MESSAGEff Name: Company: Location: Fax # FROM; Name & Ext.: Department! Confirm # Mail Stop: NOTES: .il lq .. · _. - ! PAGES TO FOLLOW (Do Not Include Cover Sheet) PRIVATE SECRET CONFIDENTIAL Telecopy # Confirm #, I~ ........ . .......... ~: ........... : _ .. .................-.-.,--;,c: ;-~;:~.~__~._.;.~ _~ ~ --~.L;.; ;__~.~.7~.L;,;;_~.; ................ For Cornmunioatlons Center Use Only , Time In Time Sent Time Confirmed Operator ~'AAR 0 4 ]997 Gas Cons, Commmior, An~o~age MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Davi'td Chairman ~--- DATE: March "' ~997 THRU' Blair Wondze!~ P. I. Supervisor FROM' Bobby Foster., J- SUBJECT: Petroleum Inspector FILE NO: PI91CBEE.doc P & A Surface Plugs BPX - Gwyder Bay Unit Exploration Wells Listed Below Sunday. March 2. 1997: Pete's Wicked # 1-PTD # 97-0010 - I trveled this date to BPX's exploration location and inspected the top of the cement plug in the cut off casing was level with the top of the casing and to insure that the casing was cut off 3' below the tundra level. The cement was in place and a plate was welded over the casing with the name of the oil company, the footage from the South and East control lines, section, township, range and meridian bead welled on the plate. Pete's Wicked # 2 - PTD# - NOT ISSUED - This well was not drilled - only 80' of conductor pipe was set. A I0' cement plug was placed at the top of the casing and a plate with ail information as described above was in place. Eiger ¢I- PTD#- NOT iSSUED - This well was not drilled - only the 80' of ,.,onc]uc,,.,r was set..~, 10' cement was placed at the top of the casing and a plate with all information as describe above was in place. Gravel will be placed in the cellars and the location will have to be inspceted this summer to check for subsidience and trash on thelocation. Summary: I inspected the cut off casing on above listed wells to insure that cement was in place and theP & A marker plates were welded on and required information was bead welded on them. All passed inspection. Attachment: Pictures do~.. removed Unciassified X__ Confidential (Unclassified if '" ALASKA OIL GAS CONSERVATION COMMISSION TONY KIVOWLE$, GOVE/~IVO/~ 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276,7542 February21,1997 Paul Prince, Senior Drilling Engineer ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 995 I94612 Re: Well # Company Permit # Surf Loc Btmhole Loc Gwyder Bay Eiger #1 ARCO Alaska, Inc. 97-28 1378q',/SL, 2648'WEL, Sec 15, T12N, R13E, UM 92YSNL, 1494'EWL, Sec 23, T12N, R13E, UM Dear Mr. Prince: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the David ~hnston Chairman BY ORDER OF THE COMMISSION dlf/encl c: Dept offish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASK/-~ OIL AND GAS CONSERVATION COMMISSION CONFIDENTIAL PERMIT TO DRILL 20 AAC 25.005 [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Typeofwork []Re-Entry []DeepenI I-'lService I-IDevelopment Gas []Single Zone I-IMultiple Zone 12. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan RTE = 56.22' Gwyder Bay 3. Address 16. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028276 i4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1378' NSL, 2648' WEL, SEC. 15, T12N, R13E Gwyder Bay At top of productive interval 8. Well Number Number U-630610 603' SNL, 824' EWL, SEC. 23, T12N, R13E Eiger #1 Attotal depth 9. Approximate spud date Amount $200,000.00 923' SNL, 1494' EWL, SEC. 23, T12N, R13E 02/21/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL385195, 923' I Pete's Wicked #1, 60' @ sudace - 3477' TVD 640 11877' MD / 10200' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e) (2)} Kick Off Depth 3600' Maximum Hole Angle 51.o7° Maximum surface 3815 psig, At total depth (TVD) 9600' / 4775 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 32" 20" 91.5# H-40 Btc 80' 40' 40' 120' 120' 260 sx Arctic Set (Approx.) 13-1/2" 10-3/4" 45.5# L-80 Btc 3450' 40' 40' 3490' 3490' 1266 sx Coldset III, 346 sx 'G' 9-7/8" 7-5/8" 29.7# L-80 Mod Btc 10669' 40' 40' 10709' 9466' 681 sx Class 'G' 6-3/4" 5-1/2" 17# L-80 Mod Btc 1318' 10559' 9372' 11877' 10200' 170 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cements(;( ?-,Q, \ MD TVD Structural Conductor Surface " Intermediate ProductionR E C £1V E D Liner Perforation depth: measured Alaska 0il & Gas Cons. Commission true vertical Anchorage 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Ddlling Program [] Drilling Fluid Program [] Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/N~m~er:_ , Floyd ~'l~*~nandez, 564-5960 Prepared By Name/Number: Kathy Campoamor, 564-5122 21. I .h. ereby certify that the f~e_~oino is ~u~ a{nd/'correct to the best of my knowledge Signed ~'~ ~{"~"~("--"'"'~//'-'/-~ ¥// - ~ I' '~'/ Pau, Pr,nce Title Senior Drilling Engineer Date ~ _ Commission Use Only Permit Number I APl Number Approval Date I See cover letter ¢,~-? ~' 50- 0 :~_.~ - ~-- 2. ~ ~",_,~ ~,~-.- ~/ '-" ~'"'~ for other requirements Conditions of Approval: Samples Required [] Yes [] No Mud Log Required ~ Yes [] No Hydrogen Sulfide Measures []Yes '~ No Directional Survey Required ,,~ Yes [] No Required Working Pressure for BOPE [] 2M; []3M; ~ 5M; [] 1OM; [] 15M Other: by order of Approved By - .~!!rl~l ~i~rlSd i~¥ Commissioner the commission Date6~"C~/~p'~ Form 10-401 Rev. 12-01-85 ]a~id W. johnston Submit In Triplicate WELL PLAN WELL: Eiger #1 LOCATION: Surface: Target (Secondary): Target (Primary): T.D.: ESTIMATED START: OPR. DAYS TO COMPLETE: CONTRACTO~ 1378' FSL 11' FSL 603' FNL 923' FNL February 21, 1997 2648' FEL Sec 15 T12N R13E 440' FEL Sec 15 T12N R13E 824' FWL Sec 23 T12N R13E 1494' FWL Sec 23 T12N R13E RECi:'iV'ED r :.B '10 1.997 25 days (20 days drill and log; 5 days to complete) Alasl(~ 0il & 6as Cons. Comm, lssiorl Doyon Drilling' Rig #14 A~ch0rago MAX ANGLE/AZIMUTH/KOP/BUILD/BUILD #2/MAX DEP: S-Shape wellbore 51.07°/115.51°/3600'/6°/2.5°/4741' Ground level elevation is 16.3' AMSL. KB to ground level elevation is 39.92'. Close Approach Wells - Pete's Wicked #1(60' from surface to surface casing shoe @ 3477' TVDss) W. Storkerson #1 (1000' southwest of Eiger #1 surface location) Drilling Hazards 1) Low potential for encountering shallow gas or oil shows and accumulations is evidenced by mud logs for West Storkersen #1, Kup Delta #1 and Pete's Wicked #1 wells. 2) Regional offset data confirm a very Iow probability of encountering any shallow gas or abnormal pressures. 3) No H2S or CO2 EXPECTED PORE PRESSURES AND FRACTURE GRADIENTS: Depth ('TVDBRT) 0'- 3490' 3490' 3490'- 9466' 9466' 9466'-10200' 10200' Strata / Casing Point Tertiary 10-3/4" casing shoe Tertiary-J urassic 7-5/8" casing shoe Triassic- Permian 5-1/2" Liner shoe Pore pressure (ppg EMW) 9.0 9.0 9.6 9.6 7.7 - 9.6 CASING PROGRAM: Hole Csg Wt(Ib/ft) Grade Conn Length 32" 20" 91.5# H-40 BTC 80' 1 3- 1/2" I 0-3/4" 45.5# L-80 BTC 3450' 9-7/8" 7-5/8" 29.7# L-80 MODBTC 10669' 6-3/4" 5-1/2" 1 7# L-80 MOD BTC 1318' Fracture Gradient (ppg EMW) 11.0-->13.0 13.0-->15.5 Top Btm ('MD) 40' 120' 40' 3490' 40' 10,709' 10,559' 1 1,877' LOGGING PROGRAM: Open Hole - 13-1/2" Hole: 9-7/8" Hole: 6-3/4" Hole: Cased Hole Mud Logging MWD: Dir only E-line: RES/SP/G R/LDT/CN L/Cal/BHC Mud Logging MWD: Dir, Gamma Ray & Resistivity E-Line: RESIS PIG R/LDT/CN L/CaI/BHC Percussion Sidewall Cores/GR (optional) Mud Logging MWD: Dir, Gamma Ray & Resistivity E-line: RES/S P/G R/LDT/CN L/Cal/B HC MDT/GR (optional) CBL maybe run in both intermediate & production casing OPERATIONS CONTACT: Principal Contact: Floyd Hernandez Alternate Contacts: Paul Prince David Nims Work Phone- 564-5960 Home Phone- 696-8971 Pager - 275-1908 Work Phone - 564-5589 Home Phone- 345-6867 Work Phone - 564-5219 Home Phone- 346-2026 Pager- 275-4539 Due to the confidential nature of this well, please limit communications to the above 3 people. At least one will be available at all times until the end of operations. PROPOSED DRILLING PROGRAM WELL: Eiger #1 Ice construction from Prudhoe Bay T-Pad to the Pete's Wicked well location has been completed. The Eiger #1 well will be drilled from the same ice pad as the Pete's Wicked #1 well. The rig will be placed on rig mats and herculite. Drilling Operations: (All depths are approximate) Note: The Eiger #1 conductor hole has been pre-drilled to 120' MD. The 20" conductor has been set and cemented. Move in, rig up. Accept rig for operations. Nipple up diverter and function test same. The well will be drilled as a slant wellbore. Drill 13-1/2" hole vertically to casing point at 3490' MD. Run openhole logs. Run and cement 10-3/4", 45.5# casing to surface utilizing screw-in float equipment to cement to surface. Install blowout prevention equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and 5,000psi annular preventer. Test BOP's. Maximum anticipated possible reservoir pressure is 4125 psi (9.6 ppg EMW) at 8300' TVDBRT and 4775 psi (9.6 ppg EMW) at 9600' TVDBRT. Maximum possible surface pressure is 3815 psi based on a gas column to surface from 9600' TVDBRT. Full mudlogging facilities will be on location from spud to TD. Formation leak-off tests will be performed 20' below the 10-3/4" and 7-5/8" casing shoes. The 9-7/8" hole section will be directionally kicked off at 3600' MD and will build angle to a tangent of 30°. This hole inclination will be held to the proposed a depth of 8840' MD. From 8840' MD to 9697' MD, a 2.5°/100' build rate will be utilized to increase the hole angle to 51°. This tangent angle of 51° will be held to the proposed 9-7/8" hole TD at 10,709' MD. Run logs and possibly sidewall coring tool. Run 7-5/8", 29.7 # Mod Butt casing string to within 10' of 9-7/8" TD and cement with Class G cement. The annulus will not be used for injection of waste fluids. Drill the 6-3/4" hole to TD (--11,877' MD). Run logs. Run and cement 5-1/2" liner. Cleanout 7-5/8" casing and 5-1/2" liner. Run 4-1/2" completion string. Log and rotary core data will be used to determine whether any well tests are performed. The current plan is to test the well after the rig moves off location, but closed chamber DST's are still being considered. Any fluids produced from the well may be re-injected back into the formation. Fluids and cuttings incidental to the drilling of the well will be transported for injection into the Prudhoe Bay CC-2A disposal well. The well is planned to be suspended with the completion string left in the wellbore. the well is abandoned, the appropriate plugs and markers according to AOGCC regulations will be met. The pad will be cleaned up of any surface debris. The nearest offset wells are the Pete's Wicked #1 and West Storkersen #1 wells. The West Storkersen #1 well is located 1000' southwest of the proposed Eiger #1 surface location. The Pete's Wicked #1 well is approximately 60' away from the proposed Eiger #1 surface location.. The drilling fluid program and surface system will conform to the regulations set forth in 20AAC25.003. MUD PROGRAM: EIGER #1 MUD SPECIFICATIONS- SURFACE HOLE Surface: Mud Weight: ppg 8.6 - 9.8 Funnel Viscosity sec/qt -300 YP lbs/100ft2 40 - 60 10 sec Gel lbs/100ft2' 30 - 60 10 min Gel lbs/100ft2 60 - 80 pH 9- 10 APl Fluid loss mi/30 min 12-15 Solids % Casing point: 9.5 - 10.0 <100 20 - 40 15 - 20 20 - 30 9-10 6-10 <8 MUD SPECIFICATIONS- INTERMEDIATE HOLE, LSND Freshwater System Mud Weight ppg 9.0-11.0 Yield Point lbs/100ft2 15 - 25 Plastic Visc. 10 - 20 APl Fluid Loss mi/30 min 4-10 pH 9.0 - 9.5 Solids % <10 MUD SPECIFICATIONS-PRODUCTION INTERVAL: 3% KCL Polymer System Mud Weight ppg 9.8 - 10.2 Yield Point lbs/100ft2 15 - 25 Plastic Viscosity 10 - 20 APl Fluid loss mi/30 min 4- 6 pH 9.0 - 9.5 Solids % 10 - 23 Pore pressure prediction techniques and observation of hole conditions will be used to increase mud weight in line with increases in bottom hole pore pressure. Keeping a safe overbalance of +/- 150psi is planned, this equates to a mud weight approximately 0.3 ppg over pore pressure EMW at 9,600 TVDBRT. Disposal Cuttings Handling: Cuttings will be hauled to the ball mill at CC-2A. Fluid Handling: Will be hauled to the injection skid at CC-2A. 10-3/4" SURFACE CASING CEMENT PROGRAM CIRC. TEMP 45°F SPACER: 75 bbls fresh water ahead of lead slurry. LEAD CEMENT TYPE: Coldset III WEIGHT: 12.2 ppg YIELD:1.92 ft3/sx APPROX #SACKS: 1266 THICKENING TIME: > 4.0 hrs TAIL CEMENT TYPE: Class 'G' with 2% CaCl ADDITIVES: As Required WEIGHT: 15.8 ppg APPROX #SACKS: 346 YIELD:1.15 ft3/sx THICKENING TIME: > 3.5 hrs MIX WATER: 10.53 gps MIX WATER: 4.95 gps CENTRALIZER PLACEMENT: 1. Run one centralizer per joint for the first 19 joints. CEMENT VOLUME: 1. Lead slurry to surface w/200% excess. 2. Tail slurry to 750' above shoe with 30% excess + 80' float joint 7-5/8" INTERMEDIATE CASING CEMENT PROGRAM CIRC. TEMP: 140° F (Kuparuk Static BHT ~ 175° F) SPACER: 70 bbls NSCI spacer TAIL CEMENT TYPE: Class 'G' ADDITIVES: 0.3% FL-52 + 0.5% CD-32 + 0.1% A-2 + lghs FP-6L WEIGHT: 15.8ppg YIELD: 1.15ft3/sx MIX WATER: 4.95 gps APPROX #SACKS: 681 THICKENING TIME: 3.5 to 4.5 hrs CENTRALIZER PLACEMENT: 1. I centralizer per joint from 10709' MD to 9760' MD 2. 2 centralizer s per joint from 9760' MD to 8978' MD 3. I centralizer per joint from 8978' MD to 7978' MD OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 to 14 bpm. CEMENT VOLUME: 1. Cement up to 1000' above the top of the Kuparuk formation @ 8978' MD with 30% excess. 5-1/2" CASING CEMENT PROGRAM CIRC. TEMP 145© F (Ivishak Static BHT ~ 225°F) SPACER: 70 bbls NSCI spacer CEMENT TYPE: Class 'G' ADDITIVES: 150 ghs BA-86L + 0.6% CD-32 + 0.25% FL-33 + 0.2% A-2 + 0.5% Bentonite + +1 ghs FP-6L + 0.2% S-400 + R-1 (as neeed) WEIGHT: 15.7 ppg YIELD:1.19 ft3/sx MIX WATER: 3.43 gps APPROX #SACKS: 170 THICKENING TIME: 3.5 to 4.5 hm total CENTRALIZER PLACEMENT: 1. 2 centralizer s per joint through out the entire liner, except for the joint that will be reciprocated across the shoe. 2. 1 centralizer per joint across the liner lap LINER CEMENT VOLUME: 1. 200' height of cement above top of liner + 30% excess Eiger #1 Exploration Well Application for Permit to Drill Doyon Rig #14 - Available fluid storage capacity on-site. Active Mud System Hole-fill/trip tank - 54 bbls Desander suction pit - 153 Degasser suction pit - 173 bbl$ Desilter suction pit - 135 bbls Centrifuge/volume suction pit - 130 bbls Suction pit - 283 bbls Pill pit- 43 bbls Slug pit - 27 bbls Total - 998 bbls Rig Water System Water tank - 6900 gallons Information on ricj diverter line: Single Diverter line OD is 16". Eiger #1 Pore Pressure / Fracture Gradients Pore Pressure Seismic data in the vicinity of Eiger Cf1 has been reviewed in conjunction with offset well records (mud logs, DST data, sonic logs and offset seismic). This analysis has indicated that there is no abnormal pressures in the area. Virgin reservoir pressures (9.6 ppg EMW) are expected in both the Kuparuk and ivishak formations. Mud weights up to 11.0 ppg may be necessary to stabilze the Miluveach and Kingak shales below the Kuparuk formations. The pore pressure in the Ivishak may be as Iow as 7.7 ppg EMW based on pressure data from the North Prudhoe Bay #3 well. Fracture Gradient Information available from the offset wells (Pete's Wicked #1, W. Storkerson #1, Pt Mac #12, & P1-09) have been reviewed to provide a best estimate of fracture gradients to be expected. 10-3/4" casing point (3490'TVDBRT) should provide a fracture gradient of 11.0 - 13.0 ppg EMW. This will be sufficient to drill to the planned TD of the 9-7/8" hole section at 9466'TVDBRT. Fracture Gradient at the 7-5/8" shoe will be approximately 13.0 - 15.5 ppg EMW, sufficient to drill to the planned TD of 10200'TVDBRT. Kick tolerance monitoring and pore pressure determination techniques Kick tolerance volume will be continually updated as the well is in progress, incorporating the most up-to-date data available from the well. The real-time resistivity log incorporated in the MWD assembly will enhance the mud logging crew's ability to monitor for change in pore pressure in addition to the normal techniques of D-Exp. projections, cuttings quality, connection gases etc. EIGER #1 Anticipated Pore Pressure/Mud Weight/Fracture GradiE 1000 200O 3000 4000 50OO 6000 700O 8OOO 9000 1OOOO 11000 ppg EMW 7 8 9 10 11 12 13 14 15 16 I~· Min. Franc Grad \. I~ · M~ x Frac G rad "ight I~ % , Fop Kup~ruk (8~ Top of ~ilu c~ (8870' TVD) Top of Kinga~ (9260' T~'D) lop of Sadloroch t (~00' I PressurefHazard Analysis for Eiger No. 1 LITHOLOGIES:(based on West Storkersen-1, Gwydyr-01, & PW #1 wells) The well is forecast to drill through unconsolidated gravels and coarse sand to + 1000' TVDss. o-~1000'-4000'TVDss, the lithologies will be poorly consolidated bedded sands, gravels and clays with common woody material and occasional lignite throughout the section. These lithologies are similar to those observed throughout the North Slope. The transition out of the permafrost layer will be between 1800-2000' TVDss; however, surrounding well control indicates possibility of more variable permafrost thickness. SHOWS' Occasional ( methane C1) lignites and associated gas shows are anticipated, as seen at Gwydyr-01 and Pete's Wicked No. 1 (2000-4000') WELL BORE PRESSURES: Abnormal Pressure / Temperature Zones: None expected. Anticipated pore pressures should range from 8.5-9 ppg +.3ppg. The Ivishak formation may be slightly underpressured, +8.1 ppg, as evidenced in the North Prudhoe Bay #3 well in the same terrace fault block approximately six miles to the east. POTENTIAL HAZARDS ! PITFALLS: · Presence of H2S or CO2 Gas: CO2 in the range of 8-12% expected based on composition of gas tested from wells in the Prudhoe area. Faults Penetrating well-bore: The planned wellbore will cross a fault (+ 350' throw) in the Miluveach formation at approximately 9210' TVDss. Loss circulation material will be stored on site to help any potential loss circulation problems. There is no high resolution seismic survey data available over the intended well path and the conventional 3D seismic data does not have sufficient resolution over the requked interval for analysis. However, analysis of offset well data (mud logs and completion reports) indicates that there is a very low chance of encountering shallow (below permafrost to 5000') gas and oil accumulations as evidenced by mudlogs for Pete's Wicked No. 1, Gwydyr-01, West Storkersen-01 (200'- 4500') and Kup Delta 51-01 (500'-4500'). Regional offset data conf'mn a very low probability of encountering any shallow gas or abnormal pressures in this section of the hole. Even though we do not expect to encounter any shallow gas, Doyon Rig #14 will be equipped with the following gas detection system: · Rig gas sensors located at the pits, cellar, & rig floor · PVT system · Trip tank · EPOCH Well Logging - Specialized personnel - Total Hydrocarbon Analyzer (FID) - Gas Chromatogragh (FID) Usual SSD procedures will be followed to minimize any potential for a shallow gas kick. Sufficient hydrostatic colunm will always be maintained while drilling the well and the correct tripping procedures will be followed while tripping in and out of the hole. If a shallow gas kick is taken prior to setting surface casing, the gas kick will not be shut-in, but diverted through the diverter system. EIGER #1 EXPLORATION WELL CASING DIAGRAM 20" Conductor 91.5#, H-40, BTC 10-3/4" casing 45.5#, L-80, BTC 7-5/8" casing 29.7#, L-80, Mod Butt 5-1/2" Liner 17#, L-80, MOD BTC 120' MDBRT 80' BGL · ca. 3490' MDBRT ca. 3490' TVDBRT Top of Liner @ 10,559' MDBRT @ 9,372' TVDBRT ca. 10,709' MDBRT ca. 9,466' TVDBRT ca. 11,877' MDBRT ca. 10,200' TVDBRT CONFIDENT AL Shared Services Drilling[ Sfrucfure'EXEiger Well'Eiger#1 Field'Exploration Location'Alaska 0 -800 - 0 c5 - O0 0 - -- _~ 800 - o (D - 1600 ~ 2400 - O_ - 3200 - _ -- 4000 - 4gO0 - _ ~00 - - ~ 7200 - II - ~ ~000 - 8800 - 9600 - -- 1O4OO - 11200 Eiger #1 Wp9I Tie on Base permafrost: 1910 MD WELL PROFILE DATA .... Point .... MD Inc Dir TVD North EastBLS (deg/lOOft) Tie on 0 0.00 0.00 0 0 0 0.00 KOP Start dir 6/~O0 3600 0.00 0.00 3600 0 0 0.00 End dir. 4100 30.00 121.64 4077 -67 109 6.00 Start dir 2.5/100 8840 30.00 121.64 8182 -1511 2127 0.00 End dlr. 9697 51.07 115.50 8830 -1569 2615 2.50 ~Torget Kup Torg 9760 51.07 115.50 8870 -1591 2_660 0.00 targetIvishok Terg 10922 51.07 I 15.519600 -- 1980 3476 0.00 TD 11877 51.07 115.51 10200 --2300 4146 0.00 Checked:_ X: 646486.2.9 Y: 5993911.29 J L Top Sy5: 3480 MD 10 5/4" Surface Casina: 3490 MD 6.oo Star{dir. 6/100: 3600'MD \ 1,~.o% x~2340-0(:~0 End Dir. :4100 MD Top Ugnu: 4559 MD _ $: 4634 MD Sail Angle: 30 degrees ~ West Sak: 6516 MD bee: 6789 MD Top HRZ: 8560 MD ~ Start dir. 2.5/1 O0: 8640 MD ~ 32.48 Kuparuk: 8'978, MD ~ 37.$8 42.3o 'x "'--47'23 End Oir ' 01597 MD Miluveach: 0760 MO ~x.51-o7 ' ' Kmgok . 103gl MD 7 5/~ Intermediote ' 1070~ ~ Shublik 2 10835 M~ ' ~ ~ Ivishok ~ 10922M~ ~ Kovik: 11559 MD TD / 5 1/2' Liner: 11877 MD ~ APPROVED I I I I I I I I I I I I I I I I 1 I -800 0 800 1600 2400 3200 4000 4800 5600 6400 Scole 1 ' 800.00 Vertical Section on 119.02 azimuth with reference 0.00 N, 0.00 E from Eiger ~1 CONE DENTIAL N TRUEHORTH eck X: 6464B6.29 Y: 5993911.29 APPROVED JShared Services DrillingI Structure' EX Eiger Well: Eige:~slI I Field'Exploration Location'A ka TARGET DATA MD Inc Dk ~ No,th £a~. -- Name .... PosRJon -- 10922 51.07 115.51 960~ -1980 3476 Iv~hok Terget650000,5992000 9760 51.07 115.50 8870 --1591 2660 Kulxiruk Target 649177,5992375 ._ Scale 1 ' 400.00 East -> -400 0 400 800 1200 1600 2000 2400 2800 S200 5600 4000 4400 8OO I 4oo - 0 I -400 - A I II -~oo- I (-- -1200- i ~_ - 0 -1600- :Z: _ -2000- o -2400- 0 0 - 0 · - -2800- _ -- m -3200- 10 3/4" Surface C~slng: 3490 MD 0 ..~ 3500 .~oo oo oo ~o 0o 7~o Kuparuk Target ~5~s hak Target 7 5/8- Interm~dlale casing: 10709 MD 5 I/2" Production Liner: 11877 MD I I I I I I I I I I I I I I I I I I I I I I I 8OO -- - 400 -- - 0 -- - -400 - A - -800 II -- --1200 Z - 0 --1600 ._+_ _ :Dr'. --2000 -- --2400 ~ - N --2800 '- 0 -- o 0 -3200 o --400 0 400 800 1200 1600 2000 2400 2800 5200 3600 4000' 4400 Scale 1 ' 400.00 East ger #1 [ical Section 119.02 50.10' MD Inc. Azi. 0.00 0.00 0.00 1910.10 0.00 0.00 3480.1 0 0.00 0.00 3490.1 0 0.00 0.00 3600.00 0.00 0.00 3700.00 6.00 121.64 3800.00 12.00 121.64 3900.00 18.00 121.64 ~000.00 24,00 121.64 4100.00 30.00 121.64 4100.02 30.00 121.64 ¢200,00 30,00 121.64 4300,00 30.00 121.64 4400.00 30.00 121.64 4500.00 30.00 121.64 4559.14 30.00 121.64 4600.00 30.00 121.64 4634.20 30.00 121.64 4700.00 30.00 121.64 4800.00 30.00 121.64 4900.00 30.00 121.64 5000.00 30.00 121.64 5100.00 30.00 121.64 5200.00 30.00 121.64 5300.00 30.00 121.64 5400.00 30.00 121.64 5500.00 30.00 121.64 5600.00 30.00 121.64 5700.00 30.00 121.64 5800.00 30.00 121.64 5900.00 30.00 121.64 6000.00 30.00 121.64 6100.00 30.00 121.64 6200.00 30.00 121.64 6300.00 30.00 121.64 6400.00 30.00 121.64 6500.00 30.00 121.64 6516.39 30.00 121.64 6600.00 30.00 121.64 2/11/97 10:26 AM TVDss TVDrkb Rect. Coordinates Northing Easting -50.10 0.00 0.00n 0.00e 1860.00 1910.10 0.01n 0.00e 3430.00 3480.10 0.02n 0.00e 3440.00 3490.10 0.02n 0.00e 3549.90 3600.00 0.00n 0.00e 3649.72 3699.82 2.74s 4.45e 3748.44 3798.54 10.95s 17.77e 3844.99 3895,09 24.52s 39.79e 3938.30 3988.40 43.31s 70.28e 4027.36 4077.46 67.12s 108.92e 4027.39 4077.49 67.13s 108.93e 4113.98 4164.08 93.36s 151.49e 4200.58 4250.68 119.59s 194.06e 4287.18 4337.28 145.82s 236.62e 4373.78 4423.88 172.06s 279.19e 4425.00 4475.10 187.57s 304.37e 4460.38 4510.48 198.29s 321.76e 4490.00 4540.10 207.26s 336.32e 4546.98 4597.08 224,52s 364.33e 4633.59 4683.69 250.76s 406.90e 4720.19 4770.29 276.99s 449.47e 4806.79 4856.89 303.22s 492.03e 4893.39 4943.49 329.46s 534.60e 4979.99 5030.09 355.69s 577.17e 5066.59 5116.69 381.92s 619.74e 5153.19 5203.29 408.16s 662.31e 5239.79 5289.89 434.39s 704.87e 5326.39 5376.49 460.63s 747.44e 5413.00 5463.10 486.86s 790.01e 5499.60 5549.70 513.09s 832.58e 5586.20 5636.30 539.33s 875.15e 5672.80 5722.90 565.56s 917.71e 5759.40 5809.50' 591.79s 960,28e 5846.00 5896,10 618.03s 1002.85e 5932.60 5982.70 644.26s 1045.42e 6019.20 6069.30 670.49s 1087.99e 6105.80 6155,90 696.73s 1130.56e 6120.00 6170.10 701.03s 1137.53e 6192.40 6242.50 722.96s 1173.12e Grid Coordinates DLS Easting No~hing deg/100ff 646486.29 5993911.29 0,00 646486.29 5993911.29 0.00 646486.29 5993911.31 0.00 646486.29 5993911.31 0.00 646486.29 5993911.29 0.00 646490.80 5993908.63 6.00 646504.27 5993900.69 6.00 646526.55 5993887.56 6.00 646557.40 5993869.37 6.00 646596.49 5993846.32 6.00 646596.50 5993846.31 6.00 646639.57 5993820.93 0.00 646682,64 5993795.53 0.00 646725.71 5993770.14 0.00 646768.78 5993744.75 0.00 646794.25 5993729.73 0.00 646811.85 5993719.35 0.00 646826.58 5993710.67 0.00 646854.92 5993693.96 0.00 646897.99 5993668.57 0.00 646941.06 5993643.18 0.00 646984.13 5993617.78 0.00 647027.20 5993592.39 0.00 647070.27 5993567.00 0.00 647113.34 5993541.60 0.00 647156.41 5993516.21 0.00 647199.48 5993490.82 0.00 647242.55 5993465.43 0.00 647285.62 5993440.03 0.00 647328.69 5993414.64 0.00 647371.76 5993389.25 0.00 647414.83 5993363.85 0.00 647457.90 5993338.46 0.00 647500.97 5993313.07 0.00 647544.04 5993287.68 0,00 647587.11 5993262,28 0.00 647630.19 5993236.89 0.00 647637.25 5993232.73 0.00 647673,26 5993211.50 0.00 Page 1 of 3 Vertical Section 0.00 0.00 -0.01 -0.01 0.00 5.23 20.85 46.69 82.47 127.80 127.82 177.76 227.71 277.66 327.61 357.15 377.56 394.64 427.51 477.46 527.41 577.36 627.31 677.26 727.21 777.16 827.11 877.06 927.01 976.96 1026.91 1076.86 1126.81 1176.76 1226.71 1276.66 1326.61 1334.80 1376.56 Comment Base permafrost: 1910 MD Top SV3: 3480 MD 10 3/4" Surface Casing: 3490 MD Start dir. 6/100: 3600 MD End Dir,: 4100 MD Top Ugnu: 4559 MD K-15: 4634 MD West Sak: 6516 MD iger #1 'tical Section B 119.02 50.10' MD Inc. Azl, ~700.00 30.00 ~788.91 30.00 6800.00 30.00 6900.00 30.00 7000.00 30.00 7100.00 30.00 7200.00 30.00 7300.00 30.00 7400.00 30.00 7500.00 30.00 7600.00 30.00 7700.00 30.00 7800.00 30.00 7900.00 30.00 8000.00 30.00 8100.00 30.00 8200.00 30.00 8300.00 30.00 8400.00 30.00 8500.00 30.00 8560.25 30.00 8600.00 30.00 8700.00 30.00 8800.00 30.00 8839.80 30.00 8900.00 31.47 8978.39 33.38 9000.00 33.91 9100.00 36.36 9200.00 38.82 9300.00 41.28 9400.00 43.74 9500.00 46.21 9600.00 48.68 9696.66 51.07 9700.00 51.07 9760.48 51.07 9800.00 51.07 9900.00 51.07 121.64 121.64 121.64 121.64 121.64 121.64 121.64 121.64 121.64 121.64 121.64 121.64 121.64 121.64 121.64 121.64 121.64 121.64 121.64 121.64 121.64 121.64 121.64 121.64 121.64 120.99 120.21 120.01 119.15 118.38 117.69 117.07 116.50 115.97 115.50 115.50 115.50 115.50 115.50 2/11/97 10:26 AM TVDss 6279.01 6356.00 6365.61 6452.21 6538.81 6625.41 6712.01 6798.61 6885.21 6971.81 7058.42 7145.02 7231.62 7318.22 7404.82 7491.42 7578.02 7664.62 7751.22 7837.82 7890.00 7924.43 8011.03 8097.63 8132.10 8183.84 825O.O0 8267.99 8349.76 8429.00 8505.54 8579.25 8649.98 8717.61 8779.90 8782.00 8820.00 8844.83 8907.67 TVDrkb 6329.11 6406.10 6415.71 6502.31 6588.91 6675.51 6762.11 6848.71 6935.31 7021.91 7108.52 7195.12 7281.72 7368.32 7454.92 7541.52 7628.12 7714.72 7801.32 7887.92 7940.10 7974.53 8061.13 8147.73 8182.20 8233.94 8300.10 8318.09 8399.86 8479.10 8555.64 8629.35 8700.08 8767.71 883O.OO 8832.10 8870.10 8894.93 8957.77 Rect. Coordinates Northing 749.19S 772.52S 775.435 801.66S 827.89S 854.13S 880.36S 906.60S 932.83S 959.06S 985.30S 1011.53S 1037.76S 1064.00S 1090.23S 1116.46S 1142.70S 1168.93S 1195.16S 1221.40S 1237.20S 1247.63S. 1273.87S 1300.10S 1310.54S 1326.53S 1347.91S 1353.92S 1382.32S 1411.66S 1441.89S 1472.96S 1504.80S 1537.35S 1569.44S 1570.56S 1590.81S 1604.05S 1637.54S Easting 1215.69e 1253.54e 1258.26e 1300.83e 1343.40e 1385.96e 1428.53e 1471.10e 1513.67e 1556.24e 1598.81e 1641.37e 1683.94e 1726.51e 1769.08e 1811.65e 1854.21e 1896.78e 1939.35e 1981.92e 2007.56e 2024.49e 2067.05e 2109.62e 2126.56e 2152.85e 2189.03e 2199.39e 2249.45e 2302.92e 2359.71e 2419.72e 2482.81e 2548.89e 2615.47e 2617.81e 2660.27e 2688.02e 2758.23e Grid Coordinates DLS Easting Northing deg/100ff 647716.33 5993186.10 0.00 647754.62 5993163.53 0.00 647759.40 5993160.71 0.00 647802.47 5993135.32 0.00 647845.54 5993109.92 0.00 647888.61 5993084.53 0.00 647931.68 5993059.14 0.00 647974.75 5993033.75 0.00 648017.82 5993008.35 0.00 648060.89 5992982.96 0.00 648103.96 5992957.57 0.00 648147.03 5992932.17 0.00 648190.10 5992906.78 0.00 648233.17 5992881.39 0.00 648276.24 5992856.00 0.00 648319.31 5992830.60 0.00 648362.38 5992805.21 0.00 648405.45 5992779.82 0.00 648448.52 5992754.42 0.00 648491.59 5992729.03 0.00 648517.54 5992713.73 0.00 648534.66 5992703.64 0.00 648577.73 5992678.25 0.00 648620.80 5992652.85 0.00 648637.95 5992642.75 0.00 648664.54 5992627.28 2.50 648701.13 5992606.61 2.50 648711.60 5992600.80 2.50 648762.20 5992573.39 2.50 648816.24 5992545.11 2.50 648873.60 5992516.00 2.50 648934.20 5992486.11 2.50 648997.90 5992455.52 2.50 649064.60 5992424.27 2.50 649131.79 5992393.49 2.50 649134.15 5992392.42 0.00 649177.00 5992373.00 0.00 649205.00 5992360.31 0.00 649275.85 5992328.21 0.00 Page 2 of 3 Vertical Section 1426.51 1470.92 1476.46 1526.41 1576.36 1626.31 1676.26 1726.21 1776.16 1826.11 1876.06 1926.01 1975.96 2025.91 2075,86 2125.81 2175.76 2225.71 2275.66 2325.61 2355.7O 2375.56 2425.51 2475.46 2495.34 2526.08 2568.09 2580.07 2637.61 2698.61 2762.94 2830.48 2901.10 2974.67 3048.45 3051.04 3098.00 3128.69 3206.33 Comment Seabee:6789 MD To~RZ · 8560 MD Start dir. 2.5/100 · 8840 MD Kuparuk · 8978 MD End dir. · 9697 MD Miluveach'9760 MD iger #1 ' rtical Section ~B 119.02 50.10' MD Inc. Azi. 0000.00 51.07 115.50 0100.00 51.07 115.50 0200.00 51.07 115.50 0300.00 51.07 115.50 0381.12 51.07 115.50 0400.00 51.07 115.50 0500.00 51.07 115.50 0600.00 51.07 115.50 0699.38 51.07 115.51 0700.00 51.07 115.51 0709.30 51.07 115.51 0800.00 51.07 115.51 0834.63 51.07 115.51 0900.00 51.07 115.51 0922.15 51.07 115.51 1000.00 51.07 115.51 1100.00 51.07 115.51 1200.00 51.07 115.51 1300.00 51.07 115.51 1400.00 51.07 '115.51 1500.00 51.07 115.51 1558.65 51.07 115.51 1600.00 51.07 115.51 1700.00 51.07 115.51 1800.00 51.07 115.51 11876.90 51.07 115.51 TVDss TVDrkb Rect. Coordinates Grid Coordinates Northing Easting Easting Northing 8970.51 9020.61 1671.03s 2828.45e 649346.70 5992296.10 9033.35 9083.45 1704.52s 2898.66e 649417.55 5992263.99 9096.19 9146.29 1738.01s 2968.87e 649488.39 5992231.89 9159.03 9209.13 1771.50s 3039.08e 649559.24 5992199.78 9210.00 9260.10 1798.67s 3096.03e 649616.71 5992173.73 9221.87 9271.97 1805.00s 3109.29e 649630.09 5992167.67 9284,71 9334.81 1838.49s 3179.50e 649700.93 5992135.56 9347.55 9397,65 1871.98s 3249.70e 649771.78 5992103.45 9410.00 9460.10 1905.27s 3319.47e 649842.18 5992071.54 9410.39 9460.49 1905.48s 3319.91e 649842.62 5992071.34 9416.24 9466.34 1908.59s 3326.44e 649849.21 5992068.35 9473.23 9523.33 1938.97s 3390.12e 649913.46 5992039.23 9495.00 9545.10 1950.57s 3414.43e 649938.00 5992028.11 9536.08 9586.18 1972.47s 3460.32e 649984.31 5992007.12 9550.00 9600.10 1979.89s 3475.87e 650000,00 5992000.00 9598.92 9649.02 2005.96s 3530.53e 650055.15 5991975.00 9661.77 9711.87 2039.46s 3600.73e 650125.99 5991942.89 9724.61 9774.71 2072.95s 3670.94e 650196.83 5991910.78 9787.45 9837.55 2106.45s 3741.14e 650267.67 5991878.67 9850.30 9900.40 2139.94s 3811.35e 650338.52 5991846.56 9913.14 9963.24 2173.44s 3881.55e 650409.36 5991814.45 9950.00 10000.10 2193.08s 3922.73e 650450.91 5991795.61 9975.98 10026.08 2206.93s 3951.75e 650480.20 5991782.34 10038.83 10088.93 2240.43s 4021.96e 650551.04 5991750.22 10101.67 10151.77 2273.92s 4092.16e 650621.88 5991718.11 10150.00 10200.10 2299.68s 4146.15e 650676.36 5991693.42 DLS deg/100ft 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Ve~ical Section 3283.98 3361.62 3439.26 3516.90 3579.89 3594.55 3672.19 3749.83 3826.99 3827.47 3834.69 3905.11 3932.00 3982.75 3999.95 4060.39 4138.03 4215.67 4293.31 4370.95 4448.59 4494.13 4526.23 4603.87 4681.51 4741.22 Comment Kingak: 10381 MD Sag River: 10699 MD 7 5/8" Intermediate: 10709 MD Shublik: 10835 MD Ivishak: 10922 MD Kavik: 11559 MD TD / 5 1/2" Liner: 11877 MD 2/11/97 10:26 AM Page 3 of 3 WELL PERMIT CHECKLISToo Y o FIELD & POOL /t,,,,/~. ,~, . INIT CLASS GEOL AREA PROGRAM: ex~dev [] redrlD servQ wellbore seg[] ann disp para reqQ ADMINISTRATION 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary. . 6. Well located proper distance from other wells ..... 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order ..... 12. Permit can be issued without administrative approval. . 13. Can permit be approved before 15-day wait ........ REMARKS ENGINEERING 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Conductor string provided ............... ~ N Surface casing protects all known USDWs ........ ~ N CMT vol adequate to circulate on conductor & surf cng. . N CMT vol adequate to tie-in long string to surf cng . . . Y ~N~ CMT will cover all known productive horizons ...... ~ N e o ~ ~ N Casing designs adequate for C, T, B & p rmafr st .... Adequate tankage or reserve pit ............ .~ N . ~__ If a re-drill, has a 10-403 for abndnmnt been approved..--1~_---~%'~1~' Adequate wellbore separation proposed ......... ~ N If diverter required, is it adequate .......... Drilling fluid program schematic & equip list adequate ~ ~ N BOPEs adequate .................... % ~ N BOPE press rating adequate; test to ~---d~ psig.~ Choke manifold complies w/~-PI RP-53 ~ ~.-~--~.... ~ > N~~''~ Work will occur without operation shutdown ....... Is presence of H2S gas probable ............. Y GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures. . ..Y~N 31. Data presented on potential overpressure zones .... 32. Seismic analysis of shallow gas zones ......... ~ ~ ~'~N 33. Seabed condition survey (if off-shore) . .~.~-,-.~.~ . . . 34. Contact name/phone for weekly progress reports ..... Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: d'D~. mcm~ Comments/Instructions: ×? HOW/df- A:\FORMS\cheklist rev 01/97