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Home My WebLink About196-187XHVZE Pages NOT Scanned in this Well History File 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: GraYScale, halftones, pictures, graphs, charts- Pages: ~ Poor Quality Odginal -. Pages: Other - Pages: DIGITAL DATA [] Diskettes, No. Other, No/Type .OVERSIZED Logs of various kinds n Other COMMENTS: Scanned by: ~'rb' Mildmd. Daretha Lowell [3 TO RE-SCAN Notes: D~ Ce,~nn,*,t'l h~' ~,,,...r~ ui~n~l r~mtl~ Nalhan Lowell Date: /si Og ggFO ANUARY 03 2001 W c:LO~LM-D°c Memorandum State of Alaska Oil and Gas Conservation Commissio~ Cancelled or Expired Permit Action EXAMPLE: Point McIntyre P2-36AXX AP1 # 029-22801-95 This memo will remain at the from of the subject well f'fle. 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 i the treatment of these kinds of applications for permit to ddil. 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 AP! number and in some instances the well name reflect the number of preexistin reddlls and or muitilaterais in a well. In order to prevent confusing a cancelled or expired permit witt' an active well or multilateral these case sensitive well identifiers will be changed for expired and cancelled applications for permits to ddll. 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 AP! numbenng methods descnbed in AOGCC staff memoranclum "Multi-lateral (weilbore segment) Ddiling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician TONY KNOWLE$, GO VEF/NOR OFFICE OF THE GOVERNOR OFFICE OF MANAGEMENT AND BUDGET DIVISION OF GOVERNMENTAL COORDINATION SOUTHCENTRAL REGIONAL OFFICE 3601 "C" STREET, SUITE 370 ANCHORAGE, ALASKA 99503-5930 PH: (907) 269-7470/FAX: (907) 561-6134 CENTRAL OFFICE P.O. BOX 110030 JUNEAU, ALASKA 99811-0030 PH: (907) 465-3562/FAX: (907) 465-3075 January 6, 1997 Terry Kovacevich Marathon Oil Company P.O. Box 19616o° Anchorage. Alaska 99519-6168 COMM COMB . COMB ~ L ' RES ENG -- SRENG STAT TECH ~PIPELINE COORDIN 411 WEST 4TH A VE~ ANCHORAGE, ALAS PH: (907) 271-4317/~ Dear SUBJECT: .RECEIVED .ovacevich: EXTENSION OF REVIEW SCHEDULE Kasilof Sate # I Gas Well Alaska 0il & Gas ~nB. C0mmi.a~i0n STATE I.D. NO. AK9610-03OG The Division of Governmental Coordination (DGC) is currently coordinating the state's review of the Kasilof State #1 Gas Well for consistency with the Alaska Coastal Management Program (ACMP) and has received a request from Marathon Oil Company to extend the review schedule as allowed by 6 AAC 50.110(b)(8). As discussed on Friday, January 3 and conill'meal in your follow-up memo of January 6 (attached), you do not agree with the necessity of conditions 7 and 8 in the proposed consistency finding and would like to have further discussion and resolution on these conditions. In addition, issues have als° been raised by Department of Natural Resources, Division of Oil and Gas and citizens of the Kenai Peninsula Coastal District (most recent letter is attached) which warrant further discussion and consideration. I am formally extending the review timeframe as requested by you, the applicant. The state's review will resume when the issues are resolved. Review participants will be advised if the proposed consistency finding will remain unchanged or if a revised proposed consistency finding is needed to address the conditions listed above. Please contact me at 271-4317 (E-Mail: MBIRNBAU@pipeline.state.ak.us) if you have further questions. Sincerely, Molly Birnbaum Project Review Coordinator 01-A351..H ...... : '.. ' Mr. Terry Kovacevich KasilofState/41 Gas Well State I.D. AK9610-03OG Enclosure(s) Distribution List: Margaret Spahn, KPB Glenda Landua, KPB Steve Schmitz, DNR/DOG Buz Kuby, DNR/Water Tim Smith, SHPO Don McKay, DFG Mike Luckey, DEC/SPAR Judd Peterson, DEC/Solid Waste Al Bohn, DEC/Air Dave. Jo .hnston, AO~CC Glenn Gray, DGC' ''! Mary Weger, COE.. Jeanne HanSon, NMFS Field Supervisor, USFWS Ted Rockwell,' EPA' '~' Bob Shavelson, Cook Inlet Keepers Wilson Gillespie, KPB Resident Jeff and Sylvia Beaudoin, KPB Resident Linda Wright, KPB Resident Mary Toll, KPB Resident Keith Nichols, KPB Resident -2- January. 6, 1997 SENT BY:Marathon 011 Compan) l- 6-97 ; 7'26AM Anch o ~ * ~'^-~ Al~ka Region Domestic Production 907-272-0690;# ~/ ; Marathon OilCompany P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 January 6, 1997 Ms. Molly Birnbaum Project Review Coordinator gipdine Coordinator's Office Division of'Governmental Coordination 411 West 4th Avenue, Suite 2C Anehorase, Alaska 99501-2343 Dea~ Ms. Bimbaum: Proposed Consistency Finding Kasilof Gas Well til State I.D. Number AK9610-0306 We have reviewed the conditions comained in your December 23, 1996 letter concerning the above referenced project. We do not agree with Condition 8 as stated. Condition 7 requires us to draw water from a different aquifer than that used by local residents within one-half mile of our drilling pad. The process of'drilling a water well for our project is no different than any new residential or commercial well which is permitted and should have no impact on wells nearby. As long as Condition 7 is complied with, we should not have to perform testing of other residential water wells in aquifers diff'erem than our well. Sincerely, T. ~I. KO(,acevieh Operations Sup~mend~t ILqWlN31~ISg"A 16 J'. B. Riddle - M~athon Well }:Lie KS # 1 A subsidiary ol USX Corporation Environmentally aware f~r the long run. j5FI-06-97 liON 11:03 x=~Jx. OF IflERCattTILE FaX NO. 2~9 '3 P, O1 January 4, 1997 Ms. Molly Birnbaum Project Review Coordinator Pipeline Coordinator's Office 411 West 4th Avenue, Suite 2C Anchorage, AK 99501 Re: KasilofWell #1. Project Number AKO610-030G Dear Ms. Bimbaum: ttad this project's site plan been reviewed before construction, the lack of thc recommended buffer could have been addressed. One of the conditions this consistency detemtination hinges on is that land clearing or other activity shall not occur on undisturbed areas within one hundred feet of the blaffor the edge of ravines. This damage has akeady been done ~,nd this condition cannot be met. There are no undisturbed areas Jell, as you yourself have indicated. In fact, you are requiring that soil and vegetation that have been pushed up to and over the bluffand ravine areas shall be pulled back, possibly causing further damage to the areas that were to be lek undisturbed..The district coastal management plan is not being properly implemented or complied with, however, whether or not it is enforced, I believe, is up to the state. I am, therefore, requesting an elevation of the determination. I am very concerned that this area is not large enough to accommodate the required ow hundred foot buffer. I did not receive a copy ofxhe proposed consistency finding before the first deadline, in fact, I only received a copy yesterday, hardly enough time to even meet the emended deadline. If not lbr the efforts of Glenn Gray, Project Analyst, I would have missed the opportunity to comment altogether. Sincerel.v, Linda Wrighl Box 108 Kasilof, AK 9961.0 (907) 262-9694 En¢Iosures 2 cc: Mr. Glenn Gray, Project Analyst November 21, 1996 Mr. Joe Sautner Department of Environmental Conservation 555 Cordova Street Anchorage, Alaska 99501 Subject: Marathon Oil Company request for exemption from oil spill contingency planning for the Kasilof State No. 1 gas well. Dear Mr. Sautner: In correspondence dated October 11, 1996 Marathon Oil Company requested the subject exemption as provided for in AS 46.04.050. The proposed well will be directionally drilled to an offshore location in Section 30 T3N R12W fi:om a surface location in Section 28 T3N R12W, with a total depth of approximately 15,951 feet (9,500 feet tree vertical depth). Marathon will be evaluating the dry gas potential of the Beluga and Tyonek Formations in an anticlinal structure which has been delineated by five exploration wells and seismic data. The area is located approximately eight miles due south of the Kenai gas field. The previous exploration drilling in this area was conducted between 1964 and 1975. The five wells are located structurally downdip and within a radius of approximately a mile and a half and from the proposed Marathon location. Gas chromatograph and test data fi:om these wells demonstrate the Sterling, and Upper Tyonek Formations contain only dry gas within this structure. The underlying Lower Tyonek, Hemlock and West Foreland Formations showed signs of uneconomic oil potential. The Marathon Kasilof State No. 1 well is proposed to reach total depth within the Upper Tyonek interval, in that portion of the formation which has been shown to contain only dry gas. I recommend approval of the requested exemption. The operator has done an excellent job of documenting the geologic conditions relevant to this well. These materials are too voluminous to be included here as attachments, however I will be happy to review them with you at your request. Senior Petroleum Geologist cc David Johnston TO: Bob Crandall, Alaska Oil & Gas Conservation Commission FROM' David L. Brimberry, Exploitation Geologist, Marathon Oil Compa y, Anchorage ~¢,¢-,,.. . . _ DAIfi: September ~, ~ RE' EXPECTED PRESSURE GRADIENT , ............... MARATHON KASILOF STATE //1 (MKAS1) SURFACE LOCATION: SEC. 28-T3N-R12W PTD 15,951'(9500' TVD) KENAI PENINSULA BOROUGH, ALASKA Marathon expects to encounter pressure gradients not exceeding 0.5 psi/ft (Mud Weight equivalent - 9.6 PPG (pounds per gallon)) while drilling the MKAS1. Drilling operations will use mud weights at or below 11 PPG. Surrounding well data supports this expectation and plan. These nearby wells have drilled the prospective stratigraphic section at comparable depths and with mud weights not exceeding 11.0 PPG ( pressure gradient - 0.52 psi/ft). The following offset wells recognized no overpressured section. Mesa Kasilof Unit //2, Sec. 19-T3N-R12W, TD 8000', 8.8 - 9.8 PPG, 1968 SOCAL Cape Kasilof//1, Sec. 25-T3N-R13W, TD 14,015', 10.0 - 10.8 PPG, Union Kasilof State //1, Surface Location: Sec. 28-T3N-R12W, BHL: Sec. 29- T3N-R12W, TD 16'121', 9.8 - 11.0 PPG, 1964 Union Kasilof Unit //1, Sec. 30-T3N-R12W, TD 5500', 10.2 - 10.4 PPG, 1967 1975 Drill stem tests from the drill zones also show no indication of abnormal pressure. The Mesa Kasilof Unit //2, SOCAL Cape Kasilof//1 and Union Kasilof Unit //1 tested prospective zones that will be drilled in the MKAS1. All of the tests indicate a normal pressure gradient of 0.43 psi/foot. Seismic data over the structure does indicate an anomoly. The anomoly appears not to be a shallow gas hazard. The Union Kasilof Unit //1 penetrated the feature with no dangerous pressure or gas response. The anomoly is interpreted to be a Iow velocity sediment wedge or near sea floor boulders. Test and mudlog data indicate that methane is the only hydrocarbon probable for the prospective section to be penetrated in the MKAS1. Mesa Kasilof Unit //2 and SOCALCape Kasilof //1 flowed gas to surface on drill stem tests. No liquid hydrocarbons were recovered on these tests. Mudlog shows are predominately C1. A trace of C2 was measured in the ditch gas in the SOCAL CAPE KASILOF//1 from the prospective section. The C2 is considered to be a minor component and not to indicate the presence on liquid hydorcarbons. Given the above data, no drilling hazards or liquid hydrocarbons are expected while drilling the MKAS 1. xc; P.K. Berga, Drilling Engineer, Marathon Oil Company, Anchorage J.V. Miesse, Exploitation Manager, Marathon Oil Company, Anchorage T.J. Kovacevich, Operations Manager, Marathon Oil Company, Anchorage h:\cookinle\kasilof\mkaspres TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 27, 1996 T J Kovacevich Operations Supcrintcndcnt Marathon Oil Company P O Box 196168 Anchorage, AK 99519-6168 Re: MOC Kasilof State # 1 Marathon Oil Company Permit No: 96-187 Sur. Loc. 520'FSL, 1340'FWL, Sec. 28, T3N, RI2W, SM Btmholc Loc. 3606'FSL, 5062'FEL, Sec. 30, T3N, RI2W, SM Dear Mr. Kovaccvich: Enclosed is the approved application for permit to drill the above referenced well. The penrdt to drill does not exempt you from obtaining additional permits required by laxv 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 abandoncd. The report should be a generalized synopsis of thc weck's activitics and is exclusively for the Commission's intcrnal use. Bloxvout prevention cquipmcnt (BOPE) must be tcstcd in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test pcrformcd before drilling beloxv the surface casing shoe must be given so that a representative of thc Commission mav witncss the test. Notice may bc givcn by contacting the Commission at 279-1433. David ?'. Jolmston Chairma~,~,.,) BY ORDER OF THE COMMISSION dlf/Enclosurcs CC: Dcpartmcnt of Fish &Gamc, Habitat Scction v,'/o cncl. Dcpartmcnt of Environmental Conservation w/o cncl. STATE OF ALASKA ALAS: )IL AND GAS CONSERVATION COMMISSIO -- ~,-.~ .... ~ %"'~ r,~ PERMIT TO DRILL ", - 20 AAC 25.005 la. Type of work Drill X__ Redrill __ Ilb. Type of well. Exploration ~ Stratigraphic Test m Development Oil __ Re-entry DeepenI Service Development Gas SingleZone Multiple Zone X 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Marathon Oil Company 115 feet Wildcat/Tyonek 3. Address 6. Property Designation P.O. Box 196168 Anchorage Alaska 99519-61 68 ADL 384529 4. Location of well at surface. 7. Unit or Property Name 11.Type Bond(see 20 aec 25.025) 520' FSL, 1340' FWL, SEC. 28, T3N, R12W, S.M. MOC Kasilof State At top of productive interval. 8. Well Number Number 5194234 3010' FSL, 2841' FEL, Sec. 30, T3N, R12W, S.M. MOO Kasilof State #1 At total depth. 9. Approximate Spud Date Amount $200,000 3606' FSL, 5062' FEL, Sec. 30, T3N, R12W, S.M. 12/1/1996 12. Distance to nearest 113. Distance to nearest well: 14. Number of acres in 15. Proposed depth (Md & Tvd) property line: 6951 feetI 1240 feet property: 4989 15951' (MD) 9500 (TVD) feet 16. To be completed for deviated wells: :17. Anticipated pressure (see 20 aec 25.035 (e)(2)) Kickoff depth 200 feet. Maximum hole angle 62 dog Maximum surface: 4682 psig. At total depth(b/d) 3353 psig. 18. Casing program Setting Depth Size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 20" 133 ppf B PE 80-100' 0' 0' 80-100' 80-100' Driven 17 1/2" 13 3/8" 61 ppf K-55 BTC 2505' 0' 0' 2505' 2000' 1638 sks 12 1/4" 9 5~8" 47 ppf N-80 BTC 12000' 0' 0' 12000' 6530' 2770 sks 8 1/2" 7" 29 ppf N-80 BTC 4076' 11800' 6433' 15951' 9500' 700 sks 19. To be completed for Redrill, Re-entry, and Deepening 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 Cemented Measured depth True Vertical depth Structural Conductor ~n~:a~=cliate R E C E IV E D Production Liner SEP 0 ~L 1996 Perforation depth: measured true vertical Alaska 0il & Gas Cons. Commission Anchoraqe 20. Attachments Filing fee X Property plat X BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby certify that the f~/~oing is true and correct to the best of my knowledge_ /~; Signed )--"'~,/k~. ,. )~_'~.~~ Title Operations Superintendent Date~'l~ ~ (' \ Con'mission Use Only Permit Number IAPI number I Approv/~ida Isee cover letter ~'~' '/'/¢,/~ ! 50-/?~'- 2..4::~ ~/ 7 7 '"~',~2"' ¢ ~ If°r°therrequirements Conditions of approval Samples required .~(es m No Mud log required ~ Yes __ No Hydrogen sulfide measures rYes ~No Directional survey required .~Yes ~ No Required working pressure for BOPE ~2M ~3M ,~.5M ~IOM m 15M Other: DavidOrJginalby order of ,,- / Approved by Commissioner the commission Date / ! ! Form 10-401 Rev. 12-1-85 ... Submit in triplicate DRILL.~'~'-G AND COMPLETION PROGRAM ARATHON OIL COMPANY ALASKA REGION WELL: Marathon Kasilof State #1 FIELD: PAD: A AFE No.: SLOT: NA TYPE: REVISION NO.: SURFACE LOCATION: TARGETS: Tyonek BOTTOMHOLE LOCATION: KB ELEVATION: GL ELEVATION: DATE: 8/27/96 Exploratory 6601296 Exploitation 520' FSL,1340' FWL, Sec.28,T3N,R12W, S.M. 3010' FSL,2841' FEL, Sec.30,T3N, R12W, S.M. 3606' FSL,5062' FEL, Sec 30,T3N, R12W, $.M. 115 ft. mean S.L. (est.) 80 ft. mean S.L. (est.) I. IMPORTANT GEOLOGIC HORIZONS: FORMATION DEPTH(MD-RKB) Beluga 7000 Tyonek 12245 DEPTH(TVD-RKB) 4100 6600 I1. ESTIMATED FORMATION TOPS AND CONTENT: FORMATION DEPTH(MD-RKB) DEPTH(TVD-RKB) Beluga 7000 4100 Tyonek 12245 6600 POTENTIAL CONTENT Gas Gas page 1 WELL CONTROL EQUIPMENT '- ~ ~ ~'~'~' ~'' ~ ~',~ ~' i DIVERTER ;. '~i '~, ' ~==" "~' '~ ::'=-'~,~ "~ :~ i' '~.\-- ~, i:..i · ; , ~_... The diverter will consist of a 20" or larger remotely operated annular and a 10" (minimum)O.D. vent line. The vent line valves will be full opening and integrated with the annular in the fail safe design as stipulated in 20AAC 25.035. The vent line will be a minimum of 100' from any source of ignition. BLOWOUT PREVENTERS The blowout preventer stack will consist of a 13 5/8" x 5000 psi annular preventer, a 13 5/8" x 5000 psi double gate ram type preventer outfitted with blind rams in the bottom and pipe rams in the top, a 13 5/8" x 5000 psi drilling spool (mud cross) equipped with a 3-1/16" x 5000 psi outlets, and a 13 5/8" x 5000 psi single gate ram type preventer outfitted with pipe rams. The choke manifold will be rated 3-1/16" x 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a poor- boy gas buster, and a vacuum-type degasser. A flow sensor will be installed in the flowline and the mudpits will contain sensors to measure the volume of fluid in the surface mud system. Both sensors will contain readouts convenient to the drillers console. STARTING HEAD: CASING HEADS: WELLHEAD SYSTEM 20 3/4" Flange top x 20" SOW bottom. 13-5/8" 5000 PSI top x 13-3/8" sow with base plate for 20". TUBING HEAD: CHRISTMAS TREE: IV. CASING PROGRAM: TYPE Drive pipe Surface Intermediate Production SIZE 13 3/8" 9 5/8" 7" WEIGHT 61 47 29 11" - 5000 psi top x 13 5/8"-5000 psi bottom. 3-1/8" - 5000 psi single christmas tree including two master valves, one flow tee, one swab valve one wing valve and a 3 1/8" 5000 psi top x 11" 5000 psi bottom tubing head adaptor. CASING DESCRIPTION SET SET HOLE SIZE WT. GRADE THREAD FROM TO(md/tvd) SIZE 20" 133 K-55 PE Surf 80-100/80-100 Driven 13 3/8" 61 K-55 BTC Surf 2505/2000 17 1/2" 9 5/8" 47 N-80 BTC Surf 12000/6530 12 1/4" 7" 29 N-80 BTC 11800'md 15951/9500 8 1/2" CASING DESIGN SETTING FRAC GR FORM PRSS DESIGN FACTORS GRADE DEPTH,TV @ SHOE @ SHOE MASP TENSION COLL. BURST K-55 2000 11.50 936 1070 9.16 2.98 2.93 N-80 6530 15.00 3056 4682 4.15 3.08 1.55 N-80 9500 4446 3353 8.99 4.16 2.24 page 2 V. CEMENTING PROGRAM SURFACE 13 3/8"@ 2505' MD LEAD SLURRY: Class G + required additives TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUM Surface 13.3 ppg. 1.80 cu. ft./sk gal/sk hrs:min 50 % in open hole over caliper. 100% if no caliper is run. 1155 sk CEMENT DESIGN TO BE DETERMINED TAIL SLURRY: Class G + required additives TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUM 2005 ft.15.8 ppg 1.15 cu. ft./sk gal/sk hrs:min 50 % in open hole over caliper. 100% if no caliper is run. 483 sk RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED! 1. Remove thread protectors and visually inspect connections. 2. Make up float shoe and one jt of casing. M/U stab-in float collar. Check float. Fill pipe until circulating. 3. Run remaining casing and centrilizers. CBU. Secure casing in slips. 4. R/U false rotary. Run stab-in assembly on drill pipe. 5. Circulate until no gains in circulating efficiency are made. 6. Pump spacer as follows: Spacer design to be determined. 7. Mix and pump lead slurry until spacer returns are observed, then switch to tail slurry.. 8. Displace drill pipe with mud. P/U and check that floats are holding. 9. POOH with drill pipe. 10. Washout between starting flange and 13-3/8" casing. 11. Install slip on well head. Test. 12. Nipple up BOPE and test. page 3 INTERMEDIATE: 9 5/8"(~ 12000' MD LEAD SLURRY: Class G + required additives TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUM 2000 ft. 13.3 ppg. 1.80 cu. ft./sk gal/sk hrs:min 50 % in open hole over caliper. 100% if no caliper is run. 2290 sk TAIL SLURRY: Class G + required additives Actual cement design to be determined. TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUM 10795 ft. 15.8 ppg. 1.15 cu. ft./sk gal/sk hrs:min 50 % in open hole over caliper. 100% is no caliper is run. 480 sk RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED! CASING RAMS INSTALLED AND TESTED. 1. Remove thread protectors and visually inspect connections. 2. Make up float shoe and 2 shoe joints. Check float. Fill pipe until circulating. 3. M/U float collar. (Baker-lok all connections to top of float collar) 4. Fill pipe until circulating. 5. Run remaining casing and centralizers. 6. M/U plug head and test all lines.. 7. Circulate until no gain in efficiency is observed. Pump spacer as follows: Spacer design to be determined. 8. Drop bottom plug. Mix and pump Lead slurry. 9. Mix and pump Tail slurry. Drop top plug. 10. Displace with Dowell. 11. Bump plug with 500 psi over displacement pressure. Check floats. 12, Wash out between 9 5/8" and wellhead. 13. P/U BOP stack. Set slips. N/U tubing spool. N/U BOP stack. 14, Test BOPE. page 4 PRODUCTION: 7"@ 15951' TOL @ 11800' md/6433' tvd LEAD SLURRY: CLASS g + ADDITIVES AS REQUIRED TOP OF CEMENT: ft WEIGHT: ppg. YIELD: cu. ft./sk WATER REQ.: gal/sk PUMPING TIME: hrs:min EXCESS (%): % in open hole. ESTIMATED VOLUME sk CEMENT DESIGN TO BE DETERMINED TAIL SLURRY: CLASS G + ADDITIVES AS REQUIRED TOP OF CEMENT: 11800 ft. WEIGHT: 15.8 ppg. YIELD: 1.15 cu. fl./sk WATER REQ.: gal/sk PUMPING TIME: hrs:min EXCESS (%): 50 % in open hole. ESTIMATED VOLUM 700 sk RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED! CASING RAMS INSTALLED AND TESTED. 1. Remove thread protectors and visually inspect connections. 2. Make up float shoe and 3 shoe joints. Check float. Fill pipe until circulating. 3. M/U float collar. (Baker-lok all connections to top of float collar) 4. Fill pipe until circulating. 5. Run remaining casing and centalizers. M/U liner hanger. RIH to shoe. Fill pipe and break circulation. Finish RIH. 6. Circulate and reciprocate until no gains in circulating efficiency are made. 7. Pump spacer as follows: Spacer design to be determined. 8. Pump cement. Drop dart. 9. Displace cement. Reciprocate as long as possible. 10. Bump plug w/500 psi over final circulating pressure. Check floats. 11. Set hanger. Release from hanger and CBU. POOH with DP and running tool. 12. WOC 24 hrs. 13. Clean out to TOL with 8 1/2" bit and scraper. Test liner lap. POOH. 14. Clean out liner with 6" bit and scraper. Test liner and casing. 15. Run bond log and VSP. Squeeze as necessary, 16. N/U tubing spool and test. 17. Test BOPE. page 5 VI. MUD PROGRAM MUD PROPERTIES DEPTH DEPTH WEIGHT VISCOSIT WATER MUD FROM TO ppg sec/qt LOSS TYPE 0' 2505' 8.6-9.0 100 + Gel/Water 2505' 12000' 9.0-9.5 50-70 5-10 FLO PRO/KCL 12000' 15951' 9.5-10.5 50-70 5 FLO PRO/KCL The gel/water mud will be used until hole cleaning or torque and drag warrant a change over to the FIo Pro mud system. Lub Tex will be used to reduce torgue and drag. MUD EQUIPMENT The solids control equipment will consist of two derrick floline cleaners, a 2-cone desander, a mudcleaner, and a Swaco 518 centrifuge. Maintaining Iow drill solids is extremely important when running the FIo Pro system. The finest scree possible should be run on the floline cleaners and they should be changed or patched as soon as rips develope. The mud engineer will monitor performance of the mud cleaner and centrifuge. Any deviation from peak performance will be reported the Pool Toolpusher. Pool will maintain the equipment at peak performance. VII. LOGGING, TESTING, AND CORING PROGRAMS SURFACE HOLE: INTERMEDIATE: PRODUCTION: COMPLETION: LOGGING PROGRAM AIT/SP. If shows are encountered, then LDT/CNL/NGT. Caliper for cement volumes. AIT/DSI/SP. LDT/CNL/NGT. FMI. Caliper for cement volumes. Possibly CMR, RFT, SWC. AITIDSI/SP and LDT/CNL/NGT. FMI/GR (set up to give directional survey). CST. Caliper for cement volumes. Possibly CMR, RFT. A Cement Bond Log (CET/GR) will be run prior to completion and testing. VSP. None planned. CORING PROGRAM TESTING PROGRAM Approximately 15 days of testing are planned.Testing would be through temporary test equipment with the gas being flared. VIII. BOTTOMHOLE PRESSURES AND POTENTIAL HAZARDS Hydrogen sulfide gas is not anticipated to be encountered. The Tyonek zone is expected to be normally pressured. No other known hazards. page 6 IX. OTHER INFORMATION DIRECTIONAL PLAN NORTH WEST VERT DESC MD TVD INCL AZIM COORD COORD SECTION RKB 0 0 0.00 0 0 0 0 KICKOFF, (Tie-in) 200 200 0.00 276.00 0 0 0 Build at 3.0/100 END OF BUILD 3174 2321 62.26 286.50 226 1793 1790 END OF HOLD 11629 6257 62.26 286.50 2352 8968 9271 Drop at 2.0/100 END OF DROP 12878 7057 37.34 285.00 2603 9881 10218 TOTAL DEPTH 15951 9500 37.34 285.00 3086 11681 12082 POTENTIAL INTERFERENCE: WELL DISTANCE (ft.) DEPTH (MD) No interference is anticipated for the planned well path. However, Unocal wells Kasilof #1, #2 and Kasilof Unit #1 are in the area and should be rechecked for interference if directional changes are made. DRILLING PROGRAM DRILLING Dig cellar. Drive 20" to refusal(80-100'). Put liner down where rig, tanks and camp will be located. Mobilize rig to location and dg up. Weld on starting flange with valve below flange(minimum 300 psi rating) for clean out after 13 3/8" casing job.. N/U diverter and function test. Clean out 20" casing. Drill 17 1/2" hole to 200'. K.O. and directionally drill to 2505'. Log. Run and cement 13 3/8" casing. N/D diverter. Weld on slip on head and test. N/U BOPE and test. RIH with 12 1/4" bit and drilling assembly. Test casing to 1500 psi. Drill out 13 3/8" casing and test shoe to 11.5 ppg EMW. Directionally drill 12 1/4" hole to 12000'. Log. Run and cement 9 5/8" casing. Set slips and packoff. N/U wellhead and test. N/U BOPE and test. RIH with 8 1/2" bit and ddlling assembly. Test casing to 3600 psi. Drill out and test shoe to 15 ppg EMW. Drill to 15,951'. Log. Run and cement 7" liner. Clean out to TOL with 8 1/2" bit and scraper. Test liner lap to 3600 psi. Clean out liner with 6" bit and scraper. Test liner and casing to 3600 psi. Run bond log and VSP. N/U tubing spool and test. Test BOPE. Complete and test per program. COMPLETION: Cleanout casing and liner to PBTD. Run CET/GR. Run VSP. N/U tubing spool. Test BOPE. Displace with completion flluid. Complete as per completion program. page 7 The 11.5 ppg and 15 ppg EMW shoe tests are not required to drill this Well 'but are anticipated maximum values. MASP CALCULATIONS Surface casing. 13 3/8" MASP = Injection pressure at shoe + S.F. - Hydrostatic pressure of gas column. MASP = (11.5 ppg + 1.0 ppg) x .052 x 2000' - (.115 x 2000') MASP = 1300 - 230 MASP = 1070 PSI. Intermediate casing. 9 5/8" MASP = (15 ppg + 1,0 ppg) x .052 x 6530' - (.115 x 6530') MASP = 5433 - 751 MASP = 4682 PSI Production casing. MASP = Formation pressure - Hydostatic pressure of gas column. MASP = 9.0 ppg x .052 x 9500'-(.115 x 9500') MASP = 4446 - 1093 MASP = 3353 PSI page 8 WELL PROFILE DATA ..... Point MD Inc Dir 'IVD North East V. Sect O¢g/1 O0 T~e on 0,00 0.00 276.00 0,00 0.00 0.00 0.00 0,00 End of Hold 200,00 0.00 276.00 200.00 0.00 0,00 0.00 0.00 End of Build 2239.92 61.16 276.00 1874-.00103.40-983.81 977.05 3.(30 KOP 2708.46 61.16 276.00 2100,00 146..30 - 1391.99! 382,4-20.00 End of Build/q'urn3173.77 62.26 286.50 2321.02 226.26-1792.99 1790.4.5 2.00 End of Hold 11629.44 62.26 286.50 6257.57 2351.56 -8968.40 9271.4-3 0.00 Target 12245.34 50.00 285.00 6600.00 2490.55 -9459.48 9781.76 2.00 KOP 12878.34- 37.34 285.00 7056.94 2603.45 -9880.82 10217.96 2.00 T.D. &' Tor{]et 15951.17 37.34. 285.00 9500.00 .5085.83 -11681.1112081.76 0.00 <- Wesf (feel) RATHON 0il Company t Well : K- I X I Location : Kenai Peninsula, Alaska 12800 12000 11200 10400 9600 8800 8000 7200 6400 5600 4800 4000 3200 2400 1600 800 0 800 i I I I I I I I I I I t I I I I I I I I I I I I I I I I I I I I I I 8O0 1600 2400 3200 400O 4800 5600 I.D. & Targ. et - 9500.00 Tvd. 3085.83 N, 11681.11 W ~k~--lX TGT#2 Rvsd 14-Jul-96 ~ Target - 6600.00 Tvd, 2490.55 N, 9459.48 W -~- ~-~-, ~, *** PLANE OF PROPOSAL *** · O~ ' KOP - 0.00 Inc, 200.00 Md, 200.00 Tvd, 0. 3.00 20.99 276 Az 26.98 32.98 ~ 41.97 50.97 59.96 EOC - 61.16 Inc, 2239.92 Md, 1874.00 Tvd, 977.05 Vs 61.31 Begin Build/Turn - 61.16 Inc, 2708.46 Md, 2100.00 Tvd, 1382.42 Vs End of Build/Turn - 62.26 Inc, 517.].77 Md, 2321.02 Tvd, 1790.45 Vs MAXIMUM ANGLE 62.26 DEG 4000 I-- 64O0 7200 5200 2400 1600 800 ~0 800 Created by brockway For: P. Berga Dote plotted : 15-Aug-96 Plot Reference is K-1X Version #6, Coordinates ore in feet reference K-1 X. ~True Vertical Depths ore reference RKB, 8OOO End of Hold - 62.26 Inc, 11629.44 Md, 6257.57 Tvd, 9271.45 Vs 60.85 K-1X T§t #1 - 50.00 Inc, 12245.34 Md, 6600.00 Tvd, 9781.76 Vs 52.89 46.00 40.00 End Angle Drop - 37.34 Inc, 12878.34 Md, 7056.94 Tvd, 10217.96 Vs 88OO TARGET ANGLE 37.54 DEG ~ K-IX Tgt #2 - 37.34 Inc, 15951.17 Md, 9500.00 Tvd, 12081.76 Vs 960O / I ] I ] I I I ~ I I I I I I I I I I I I I I I I I I I I I I I I I 0 800 1600 2400 3200 4000 4800 5600 6400 7200 8000 8800 9600 10400 11200 12000' 12800 Verficol Section (feet) -> Azimuth 285.00 with reference 0.00 N, 0.00 E from K-IX MARATHON Oil Company Kasilof,K-1X Exploration,Kenai Peninsula, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 0.00 0,00 276.00 0.00 200.00 0.00 276.00 200.00 300.00 3.00 276.00 299.95 400.00 6.00 276.00 399.64 500.00 8,99 276.00 498.77 PROPOSAL LISTING 600.00 11.99 276.00 597.09 700.00 14,99 276.00 694.31 800.00 17.99 276.00 790.19 900.00 20,99 276.00 884.45 1000.00 23,99 276.00 976.84 1100.00 26,98 276.00 1067.10 1200.00 29.98 276.00 1154.98 1300.00 32,98 276.00 1240.25 1400.00 35,98 276.00 1322.68 1500.00 38,98 276.00 1402.03 1600.00 41,97 276.00 1478.09 1700.00 44,97 276.00 1550.65 1800.00 47,9? 2?6.00 1619.51 1900.00 50,9? 276.00 1684.49 2000.00 53,97 276.00 1745.40 2100.00 56,9? 276.00 1802.08 2200.00 59,96 276.00 1854.38 2239.92 61,16 276.00 1874.00 2500.00 61,16 276.00 1999.45 2708.46 61,16 276.00 2100.00 2800.00 61.31 278.08 2144.05 2900.00 61,51 280.35 2191.91 3000.00 61,75 282.60 2239.42 3100.00 62,03 284.85 2286.54 3173.77 62,26 286.50 2321.02 3500.00 62,26 286.50 2472.89 4000.00 62,26 286.50 2705.65 4500.00 62.26 286.50 2938.41 5000.00 62,26 286.50 3171.18 5500.00 62,26 286.50 3403.94 6000.00 62.26 286.50 3636.71 6500.00 62.26 286.50 3869.47 7000.00 62.26 286.50 4102.24 7500.00 62.26 286.50 4335.00 8000.00 62.26 286.50 4567.76 8500.00 62.26 286.50 4800.53 9000.00 62.26 286.50 5033.29 9500.00 62.26 286.50 5266.06 10000.00 62.26 286.50 5498.82 10500.00 62.26 286.50 5731.59 11000.00 62.26 286.50 5964.35 11500.00 62.26 286.50 6197.12 11629.44 62.26 286.50 6257.37 11700.00 60.85 286.35 6290.98 11800.00 58.86 286.12 6341.20 RECTANGULAR COORDINATES 0.00 N 0.00 0.00 N 0.00 0.27 N 2.60 1.09 N 10.40 2.46 N 23.37 4.36 N 41.48 6.80 N 64.68 9.76 N 92.91 13.25 N 126.08 17.25 N 164.12 21.75 N 206.90 26.73 N 254.32 32.19 N 306.25 38.10 N 362.55 44.46 N 423.05 51 . 25 N 487.60 58.44 N 556.02 66.02 N 628.12 73.96 N 703.70 82.25 N 782.56 90.86 N 864.48 99.77 N 949.23 103.40 N 983.81 127.21 N 1210.38 146.30 N 1391.99 156.14 N 1471.62 170.20 N 1558.29 187.70 N 1644.52 208.63 N 1730.19 226.26 N 1792.99 308.25 N 2069.82 433.93 N 2494.12 559.60 N 2918.41 685.27 N 3342.71 810.94 N 3767.01 936.62 N 4191.30 1062.29 N 4615.60 1187.96 N 5039.89 1313.64 N 5464.19 1439.31 N 5888.49 · 1564.98 N 6312.78 1690.66 N 6737.08 1816.33 N 7161.37 1942.00 N 7585.67 2067.68 N 8009.96 2193.35 N 8434.26 2319.02 N 8858.56 2351.56 N 8968,40 2369.10 N 9027.91 2393.28 N 9110,93 Page 1 Your ref : K-1X Version ~6 Last revised : 15-Aug-96 Dogleg Vert Deg/lOOft Sect 0.00 0.00 0.00 0.00 KOP 3.00 2.58 3.00 10.33 3.00 23.21 3.00 41.20 3.00 64.24 3.00 92.27 3.00 125.22 3.00 162.99 3.00 205.48 3.00 252.58 3.00 304.15 3.00 360.06 3.00 420.15 3.00 484.25 3.00 552.20 3.00 623.80 3.00 698.87 3.00 777.18 3.00 858.54 3.00 942.71 3.00 977.05 EOC 0.00 1202.07 0.00 1382.42 Begin Build/Turn 2.00 1461.89 2.00 1549.24 2.00 1637.06 2.00 1725.24 2.00 1790.45 0.00 2079.08 0.00 2521.44 0.00 2963.81 0.00 3406.17 0.00 3848.54 0.00 4290.90 0.00 4733.27 0.00 5175.63 0.00 5618.00 0.00 6060.36 0.00 6502.73 0.00 6945.09 0.00 7387.46 0.00 7829.82 0.00 8272.19 0.00 8714.55 0.00 9156.92 0.00 9271.43 2.00 9333.46 2.00 9419.91 All data is in feet unless otherwise stated. Coordinates from K-1X and TVD from RKB. Bottom hole distance is 12081.83 on azimuth 284.80 degrees from wellhead. Total Dogleg for wellpath is 95.45 degrees. Vertical section is from N 0.00 E 0.00 on azimuth 285.00 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON OiL Company [asiLof,K-1X Exp[oration,Kenai Peninsula, ALaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogl Depth Degrees Degrees Depth C 0 0 R D ! N A T E S Deg/1 PROPOSAL LISTING Page 2 Your ref : K-1X Version #6 Last revised : 15-Aug-96 eg Vert OOft Sect 11900.00 56.87 285.89 6394.39 2416.63 N 9192.32 W 2.00 9504.57 12000.00 54.08 285.65 6450.49 2439.13 N 9271.98 W 2.00 9587.34 12100.00 52.89 285.40 6509.42 2460.75 N 9349.81 ~ 2.00 9664).11 12200.00 50.90 285.13 6571.13 2481.46 N 9425.72 ~ 2.00 9746.80 12245.34 50.00 285.00 6600.00 2490.55 N 9459.48 ~ 2.00 9781.76 K-1X Tgt #1 12345.34 48.00 285.00 6665.60 2510.08 N 9532.38 W 2.00 9857.22 12445.34 46.00 285.00 6733.80 2529.01 N 9603.02 W 2.00 9930.36 12545.34 44.00 285.00 6004.51 2547.31 N 9671.31 ~ 2.00 10001.06 12645.34 42.00 285.00 60T7.64 2564.96 N 9737.19 W 2.00 10069.26 12745.34 40.00 285.00 6953.10 2581.94 N 9800.55 W 2.00 10134.86 12845.34 38.00 285.00 7030.82 2598.23 N 9861.34 W 2.00 10197.79 12878.34 37.34 285.00 7056.94 2603.45 N 9080.82 ~ 2.00 10217.96 End Angle Drop 13000.00 37.~ 285.00 7153.~ 2622.55 N ~2.10 ~ 0.00 10291.75 13500.00 37.34 285.00 7551.19 2701.04 N 10245.03 ~ 0.00 10595.02 14000.00 37.34 285.00 7948.72 27'/9.53 N 10537.97 W 0.00 10898.29 14500.00 37.34 285.00 8346.24 2858.02 N 10830.91 ~ 0.00 11201.56 15000.00 37.34 285.00 8743.lr7 2936.51 N 11123.85 ~ 0.00 11504.84 15500.00 37.34 285.00 9141.30 3015.00 N 11416.78 ~ 0.00 11808.11 15951.17 37.34 285.00 9500.00 3085.83 N 1164)1.11 ~ 0.00 12081.76 K-1X Tgt #2 All data is in feet unless otherwise stated. Coordinates from K-1X and TVD from RKB. Bottom hole distance is 12081.83 on azimuth 284.80 degrees from wellhead. Total Dogleg for wellpath is 95.45 degrees. Vertical section is from N 0.00 E 0.00 on azimuth 285.00 degrees. Calculation uses the minin~Jm curvature method. Presented by Baker Hughes INTEQ CHOKE MANIFOLD PAA RIG 122 SCHEMATIC 11. 3 12. 2 13. 3 1. McEVOY TYPE C 3 1/8"-5000 PSI GATE VALVE 2. McEVOY TYPE C 2 1/16"-5000 PSI GATE VALVE 3. SWACO 2 1/16-5000 PSi REMOTE CHOKE 4. THORNHILL-CRAVEE 5 1/8"-5000 PSi IvlANUAL CHOKE 5. FLANGED TEE 2 1/16" X 2 1/16" X 2 1/16"-5000 PSI 6. 5 WAY FLOW BLOCK 5 1/8" X 3 1/8" X 2 1/16" X 2 1/16" X 2 1/16"-5000 PSI 7. 5 WAY FLOW BLOCK 3 1/8" X 3 1/8" X 3 1/8" X 3 1/8" X 2 1/16"-5000 PSI 8. 4 WAY FLOW BLOCK 2 1/16" X 2 i/16" X 2 1/16" X 2 1/16"-5000 PSI 9. 2 1/16"-5000 PSI SENSOR BLOCK 10. 2 1/16"-10,000PSI X 2 1/16"-5000 PSI SPOOL 1/8" X 2 1/16"-5000 PSI SPOOL 1/16" X 2 1/16"-5000 PSi SPOOL 1/8"-5000 PSI X 2 1/16"-5000 PSi SPOOL ~ 1/16"-10,000 PSI X 2 1/16"-5000 PSI' DOUBLE STUD ADAPTOR 1/16"-5000 PSI TARGEr FLANGE 1/8"-5000 PSI TARGET FLANGE 1/8"-5000 PSI X 2 1/16"-5000 PSI DOUBLE STUD ADAPTOR 1/8" X 3 1/8 5000 PSI SPOOL WAY FLOW BLOCK 3 1/8" X ,.3 1/8" X 3 1/8"-5000 PSI ',,3. 3ATVA ONIN3dO N3H~ N3dO NlVt413d 01 Q31V70SI 38 NV3 .8,, 3A'IVA ',,2,, · ~ ,,fl. $3A-1VA -F1V8 ONIS~ 'Z '$2S0'13 A TIVOlI V~iOlnV ,,~,, 3A'IVA 'Q3N3dO SI .3,, 3ATVA N3H~ '9 'SN3dO .C17VOIIV~ -01nv .v. SATVA 'Q2SO-D SI NVTnNNV 3H1 N2H~ lVH1 OS Q3NOIS3Q ~I31SAS 'Q3SO-IO ,(-I-IV~ION ,,3. 3A'IVA 'N3dO ,(-I-IV~tON .8. 3A -irA ,'£ 'fl?SO-lO 'NSdO ,~-17Vt41~ON 8v-lnNNV ~13VIS ~t21~t2AIQ O Z.~l 01~ Wd I ~VTnNNV ISdO00g ~ dSl41 -II~]Q,~H ~ 350'D N2dO S3'7d £ d,,U S39NY'IJ 00£ ISNV 3A-IVA 3_,41N~ 9£ '01..-I 3S073 NSdO BOP STACK CON?IGURATION 5/a r SRRA m'DRIL 13 5/8'-5000PS~ GK ANNULAR BOP SCREW HEAD 13 5/8'-5,000PSI HUB BOTTO~ CONNECTION DOUBLE Rea BoP HUB CONt~EC'nONS 4 1/I~'-5,000PS~ S~ OUTLETS WITH UANUAL LOCKS CHOKE WING KILL WING TYPE E GATE VALVE ]~E E GATE VALVE i~ 'j j HYDRIL 13 5/8"-5,000PSI MPL RAU BOP HUB CONNECTIONS 13 5/8"-5,000 PSI HUB 4 1/16'-5,000PSI SIDE OUTLETS WiTH UANUAL LOCKS X 15 5/~'-5,000 F~ F'LC. BLOW-OUT PREVENTER STACK RIG 122 D I I I ItmII' I I POOL ARCTIC ALASKA ii II TITLE SHEET SHEET INDEX I SHEET 1 OF THIS PROdECT O.P. iMILE 4.1 LOCATION MAP Scale 1" = 3000' 0 0 33 BECHAROF 54 AVENUE 35 ¢. 2 1 36 11 12 PROPOSED ROAD AND PAD PROJECT KASILOF STATE NO. 1 · 1 TITLE SHEET 2 INDEX MAP e:: EXIST. SITE PLAN 3 FINISH SITE PLAN 4 PA[:) DETAIL / NORTH PAD .,.5-6 DETAILS / NOTES 7 NORTH PAD X-SECTIONS ,, PROJECT SUMMARY NORTH PAD CONSTRUCTION 74,829 $.F. SOUTH PAD CONSTRUCTION 28,717 S.F. NORTH ACCESS ROAD 1,30' L.F. SOUTH ACCESS ROAD 150 L.F. II&r~thon 011 ¢ompnn¥ Alaska Region 8/27/96 CLIENT REVIEW ISSUE DATE DESCRIPTION McI.ANE CONSULTING GROUP P.O. :3OX 4~ 8OLDOTN~ AK ~ (907~ 283-4218 FAg((907) 283-,3~)5 HOR. SCALE: I VERT. SCALE: 1' = 5000'1 N/A DATE: 8/26/96 DRAWING NO.: 96,3066A PROJECT NO.: I BK NO.: 963O66t 96--12 HK~-I TIDE UN£ GOV. LOT iB N89'5B'4-9'E SFA'F'-j OF ALASKA '\,' \ ... -.... 298.48' .. . 'x LOT 1 R-2o' . BRUSH LIMITS .. PROPERTY LINE OF LOT 2 % ,.._. / I UMITS 170.0' ~ '"'-- ~ NORTH PAD GEOTEX~LE' 106.00' / Ngo'oo'oo'w 239.37 S89'57'O2'E ~ 76 BERM TYPICAL FOR NORTH, SOUTH & WEST PAD LIMITS · / I'?"".- '/PROPERTY LINE -.,...~ 74 % PROPERTY UNE - LOT 3 ~'~. L LOT ¢ ,28' oi $89'57'02'E 14-1.00' J DITCH SECTION =: . PROPOSED ~ SOUTH PADb-°° LOT 5 o~ LOT 6 Phone Ped~ / 1' East of op. MC S89'57'02'E 1 NBg'58't~8'W ix '11~1 Sur,m~ aC State N~. Phone Ped. 1' East of INSTALL GATE w/ POSTS WIDEN EXiSTNG ROAD TO 50' FROM HIGHWAY TO ROW LINE EDGE PAVEMENT INSTAll. GATE W/ POSTS STA. 3+00 I FINISH SITE~"-P-~'X-N l SHEET ,3 OF 7 INSTALL 50 LF 18' [}IA. CSP STA. 2+50 ........................ ROAD PER DETAIL \ ~) ~ .......... .S.T..A.:..Z.+.P.P. ACCESS ROAD TO PAD UMII'~, APPLY TOPSOIL & SI~_D STA. 1+50 NOTES / STA. 1+oo STA. 0+50 STA. 0+00 1. FINISH GRADE, CONTOURS SHOWN HEREON WITH 1' INTERVAL. 2. DOZER TRACK ALL RERMS FOR COMPACTION. 5. SOUTH PAD FOOTPRINT SHALL BE EXCAVATED TO CLEAN IN-SITU GRAVELS (APPROXIMATE DEPTH = 3.5'). STRUCTURAL FILL SOURCE LOCATED ON-SITE WESTERLY OF PAD (SEE SHEET 2). 4-. CONTRACTOR 'FO CALL ,FOR UTILITY LOCATES PRIOR TO PERFORMING EXCAVATION. 100.C ' I IMITS~ 100.00' N89'57'51 "E APPROACH W/ 30' RADIUS EACH S1DE EXTEND E'X] STING 18" DIA. CMP 16' NORTH 5' SOUTH 1156.56' LEGEND WATER WELL J KASILOF NO. 1 J KASILOF NO. 2 J PROPOSED SURFACE LOCA~ON/ 520' FSL; 1340' FWt. J TEST HOLE LOCATION ~/4 car. Marathon 011 Company Alaska Region 8/27/96 CLIENT REVIEW ISSUE BY McLANE CONSULTING GROUP P.O. BOX 468 SOI. DOTNA. AK 99~9 (907) ~ FAX (907) 283-32e5 HOR. SCALE: VERT. SCALE: 1" : 100' N/A DATE: 8/27/96 DRAWING NO.: 963066C.DWG PROJECT NO.: I BK NO.: 963066 96-12 B A PROPERTY LINE '58'29" E KASILOF NO. 2t~)(~ KASILOF NO. 1 --- .... I--4 0~''- ~ I I WATER NEW WELL ~ TRANSITio~ ~ ~LL ~ LOCATION ~ 520' FSL 1540' FWL 170.00' TOE OF BERM (DAYLIGHT LINE) PAD LIMIT ~¢l:J~z"N 90"00'00" PROPERTY LINE PAp; Z E 144.00; / TOP OF BERM 20' X 8' DRAINAGE BASIN B LINE -BERM 8:2 i~l I ./-o 50 NORTH PROP. LINE I NQRTH RAD DETAIL SECTION AA FINISHED GRADE ORIGINAL GROUND i i| '' i' ' i~ ' : " i ; q I , ,/ , ~ , i :~ ', ',, ', ', ',,', m ' ,.! /1 ~ t :oo/ : o ;oo I SHEET 4. OF 7 BERM / !82 178 35O EXCAVATE 50" BELOW 30" GRADING "A" SELECT TYPE "B" FINISH GRADE, REPLACE FILL © 95% COMP. W// GRADING "A", REMOVE ALL ORGANICS IN EXCAVATED AREA BERM SECTION BB BERM \ FINISHED GRADE ORIGINAL GROUND 82 82 80 80 78 78 76 76 /0 50 ~ 100 150 ~200 250 500 /) 550 / EXCAVATE 30" BELOW \ SELECT TYPE "B" WEST PROP. 50" GRADING "A" FINISH GRADE, REPLACE FILL @ 95% COMP. W/ GRADING "A", , REMOVE ALL ORGANICS ~ IN EXCAVATED AREA Marathon 011 Company Alaska Region · EXISTING GROUND ~~.~% TOP PAD 30"--- ' . ~:'s o~ -~1' 20' I~- N /" ~" = ~o' I ~"=~' OVER EXC. I ~ ] % / DATE: · ~ TYPE 8 I 8/26/96 N'~.S FILL - ~ DRAWING NO.: I 965066D.DWG CUT-FILL TRANSITION PROaFCT NO.: IBK NO.: CLIENT REVIEW ISSUE. DESCRIPTION I BY ~* :~i~ ~_ "-.*9 Alaska R -~ Domestic, Jduction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 September 3, 1996 Mr. Dave Johnston Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Reference: Kasilof State #1 Dear Mr. Johnston: Enclosed is the application for permit to drill the referenced well. Please advise if additional information is required. Sincerely, T. J."K'c~vacevich Operations Superintendent RECEIVED /rll'~ ,:,,,w,o~,.~.~,-~,,~ $ CP 0 4- 1996 Enclosure Alaska. 0il & G.~.s Cons. o0mmissi0~ Anch0rage A subsidiary of USX Corporation Environmentally aware for the long run. J~N-O$-97 ]'iON 11:04 K~$IL,~--..I'IERORNTILE F~X NO, 262984.~~. P, 2'2 November 9. 1996 Molly Bimbaum Division of Governmental Coordination Joint Pipeline Office 411 W. 4th Ave., Suite 2C Anchorage, Alaska 9950 ! Re: KasilofWell #1, Project number, AK9610-030G Dear Ms. Bimbauax i am submitting tiffs letter to preserve my rights to file a petition under Alaska Statute 46.40.100 on thc abe ve referenced project. It b of great concern to me that the surface work spec[fled in the proposed project has, in fact, already been done. It appears that Marathon Oil Company was right on schedule. According to their Lease Operations Application form submitted em August 14, 1996, the expected completion date for permit activity was October 10, 1996. In the SurFace Use Plan submitted thc schedule indicates the dates of September 23, 1996 to November 1, 1996, for location construction. Your letter initiating the consistency review tbr the above referenced project is dated October 30, 1.996, way atter the work was already completed. The Kcmi P¢~in_qula Borough only receivefl the project information on November 4, hardly enough time tbr the required rev/ow, public notice and public hearing before the K.PB Planning Commission and as with your consistency review, after the fact. I cannot sec how this could possibly get a fair review under the circumstances and if found to be incombtent, what could be done about it? Tki~ system does not appear to be working and on an issue of such importance to the lives ortho people in this area more respect and attention to detail must be given to this and other projects of this magnitude. Those of us who live here highly value thc quiet and clean environment and want to see it protected to the greatest degree possible. l'haak you for this opportunity to comment. Sincere~ . Linda Wright Box lOg Kasilof~ AK 99610 J~I~-06-97 ~OIq 11:04 F~tLOF HERO~NTILE F~× NO, 26o%45 December 17, 1996 Molly Birnbaum Division of Go vemmental Coordination Joint Pipeline Office 411 W. 4th Ave., Suite 2C Anchorage, Alaska 99501 Re: KasilofWell gl, Project number AK9610-030G Dear Ms. Bimbaum: I attended last evenings P 'hnning Commission meeting where this project was considered. It was not listed as a public hearing so not many people attcnded, just a few of us who have been keeping track were there. I am very disturbed about this project because I feel there is no way it can be consistent with the Coastal Management Plan. it seems to be too small aa area to aecomodate the recommended 100 ft. undisturbed buffer between the area of operation and the bluff, in t~t, the area has already been almost completely de-vegetated awfully close to the bluff. The few trees that remain look like they won't be there long. The possible encroachment on the State ,section line easement indicates a project bulging at the seams. My biggest concern, expressed in my letter of November 9, that the damage may have already been done, bctbre the review process even began, seems to have materiali~'ed. Il'this is a pre.view of what's to come with Lease Sale 85A then we are in big trouble! Thank you again for this oppommity to comment. l,inda Wright Box 108 Kasilof, AK 99610 (907) 262.9694 j~N-06-97 liON 16:49 DIV QF~OIL P, ND GaS F~iX NO, 9075623~52 P, 02.;22 MEMORANDUM DEPART~ OF NATURAL State of Alaska DIVISION OF OIL AND CA~ TO; Molly Birnbaum, DGC Date: January 6 1996 From: $geven $c.hm~tz, DNR/DO&G Kasilof 9 1 Gas Well on Loop Rd. Proposed Con~i~ency Thc Division of Oil and Gas has reviewed the proposed consistency desermination for 5he Kasilof ~ 1 gas well(s) and submits the following comments. The Division appreciates the the concerns expressed during the review process. With that said: Con~£tlon # I .is already covered by our sgandn-rd cover letter by tile sgatement... .... In addition to th~ t~z~E..and conditiOnS ~D..the lease, this approve! is subject to addizional stiDUlat±ons set forth in the enclosed attachments, and the following: The lease Sale mitigation measures are considered to be "terms and condizions %.D. the lease" To further this point, our permit includes a cody of the lease (which includes the mitigation measures) and identify it as an ~tachment. When site-specific reviews are dona and issues not covered in the review for the lease sale are made known, addition.al s=iuul~i~ns are added 5o 5~e lease operations approval. if con~itlon ~ I is added to our permit, it will have two statements (worded differently) tha~ serve uhe same purpose. I know that the KPB desires this statement be carried on our permit, but it already is. An ACFiP or enforceable policy is no~ referenced. I~ necessary, this could be added as an advi. sory to your conclusive consistency determination or applicant could be reminded of the obligation in your l~ad in paragraphs. Furthermore, if there a proposed activity that does not satisfy a requirement of the lease, 5he specific condiEion should be res~ated in the consistency determinasion, and enforceable policy referenced, or otherwiDe bo silent. JRN-06-97 lION 16' 49 DfV OF OIL AND GAS · /, F~X NO, 9075623852 Condition ~ 3 Th~ last sentence should be dropped. MaraSkons proposal does not block, interfere, or conflict with the existing access and I question the need to spcclf¥ what carl or cannot go on in ~he unuaed porLion of the section li~e easement. The courts have an extensive history regarding section line easements and what they c~n or cannot be used for, and I don't s~ any r~co~nition of that here° ~, the concern Is Eo pres~rv~ the present access to the beach, tbs firs~ sentence accomplishes that ~oai. Also, u~der rationale, I ques~£un the reference to Enforceable Policy 2.3. This section refers to "marine and astuarine waters" and does not address access concern~ on land. In addition to 5he 4.2 and 4.4 of enforce~b!e policies, this subjec~ is further covered by mitigation measures 14 and 15 of th~ lease. Condition # 4. The first sentence should be deleted. abou~ the first sentmnce. They are: I hav~ several concerns · This appears uo be a p~rmit within a permit · Does USF&WS t~ave the staff and time to do this survey. . Who will notify all the agencies when this survey is completed. e Does this mean tha~ if th~ consistency review is done, and the project found consistent with conditions attached, a lease opera~ions approval cannot be issued. In ~eneral, the condition is appropriate, ~ld the referenced enforceable policies make sense. Marathon could be required to certify that the provisions of the bal~ eagle act or district plan etc., harm been complied with prior to begi:~ing activities. Another possible solution would be to change "Prior uo issuance of Del'mits" to ~Prior to March 1...~ or some date betwe~m, now and March ! that is agreeable (and achievable) to USF&WS. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage Alaska 99501-3192 Rc~ THE APPLICATION OF MARATHON ) OIL COMPANY for an ordcr granting ) an exception to spacing rcquircmcnts of ) Title 20 AAC 25.055 to providc for thc ) drilling of Kasilof State No. 1 cxploratol3.' ) gas well. ) Consc~'ation Ordcr No. 384 Marathon Oil Company Kasilof State No. 1 Novcmbcr 6, 1996 IT APPEARING THAT: Marathon Oil Company submittcd an application datcd Octobcr 7. 1996 rcqucsting exception to 20 AAC 25.055(a)(2) to allow drilling thc Kasilof State No. I cxploratou' gas well to a producing location that is closcr than 1500 fcct to a drilling unit boundary. 2. Notice of opportunity for public hcaring was published in thc Anchorage Daily News on Octobcr 17, 1996 pursuant to 20 AAC 25.540. 3. No protests to thc application wcrc rcccivcd. FINDINGS: Thc Marathon Kasilof State No. I wcll as proposcd will be a deviated hole driilcd from a surface location 520' from thc south line and 1340' from the west linc of Section 28, T3N, R I2W. Scward Meridian (SM) to a bottom-hole location 3606' from thc south line and 5062' from thc cast linc of Scction 30. T3N. RI2W SM. 2 Marathon Oil Company is operator of'all drilling units adjacent to thc proposed Kasilof State No. 1 location. 3. An cxccption to 20 AAC 25.055(a)(2) is nccessars.' to allo~v drilling of this well. CONCLUSION: Granting a spacing cxccption to allow drilling of the Marathon Kasilof State No. 1 well as proposed will not rcsult in v~'astc nor jeopardize correlative rights. Conserx'ation Order No. 3 November 6. 1996 Page 2 NOW, THEREFORE, IT IS ORDERED' Marathon's application for cxccption to 20 AAC 25.055 for thc purpose of drilling thc Kasilof Statc No. I well is approvcd as proposed. Nm,David W. Jolmston. Cha man~ DONE alt Anchoragc, Alaska and datcd / ~ ~>""~-'-'~~"' Alaska Oil m~d Gas Conscr tion Commission Tuckcrman Babcock, Commissioner Alaska Oil and Gas Conservation Commission AS 31.()5.()81) provides that within 20 days after receipt of written notice of the entrs.' of an order, a person affected by it may file with thc Colnmission an application lbr rehearing. A request lbr rehearing must be received by 4:30 PM on thc 23rd day following thc date of thc or&r, or next working day ifa holiday or weekend, to be timely filed. Thc Commission shall grant or rcfttsc thc application in xvhol¢ or in part within 10 davs. The Cmrmfission can rclitsc an application by not acting on it within the 10-day period. An affected person has 30 days from the date the Commission rclitscs the application or mails (or otherwise distributes) an order upon rehearing, both being thc final order of thc Commission, to appeal thc decision to Superior Court. Where a request for rehearing is denied by nonaction of thc Commission, thc 30-day period lbr appeal to Superior Court nuls from tim date on xx'hich tile request is deemed denied (i.e., loth dav after tile application fi)r rehearing ,,,,'as filed). ENGINEERING · , , ·WELL PERMITCHECKLIST COMPAN ~ ~_..,_2, ? __ .,,..~?./~...~,,. U_NAM ' ' ~ PROGRAM:e devl-I reddlr-I se, ri wellboreseg I-]ann. disposal para req [] FIELD&POOL Al, ,'~, . INIT CLASS_/_~_ .... GEOLAREA ~:;'.:~_,c~ UNIT# '-'¢~, /'¢, ON/OFFSHORE ....... ADMiNis-fRATiON - . REMARKS 1. Permit fee attached ....................... /'~N , .. -- .~ ' /-, 3. Unique well name and number ................ ~. ~ ~ , / ~ , ,~ / / 4. Well located in a defined pool ................. ~---Y (N-~) ~ c-,~,~.-, ,.._~ - ~..¢ c.~,~¥, ,,~,, .., l,//~'e. ,,,' ~..,~-~,', ,-' 5. Well located proper distance from dflg unit boundary ...... ~ ~ ~' ' - '//f, /--r./ ; - -)/ ,~' ~' ///,-, / 6. Well Iocated proper distance from other wells ......... ~.~::~-'~- ~ ~,.~.,,~/_,~,.,..,v~ ,.'~-/' ~..,a ~':J'_C~,."/' ,.,J/,j//,.¢ -- ~c./,. /./ ~ ~,'~', '~'~.,--_..~.,"~-., 7. Sufficient acmoge available in drilling unit. .......... /~.~ N ~ /r __ .~ / '\ / . .,,.,/ 8. i- ............. N -. J 9. Operator only affected party ~;"~N - ,, ). /, .... ,,/ ...... 11. Permit can be issued without conservalJon order ....... _'~('~ ..j. ,/f~.~ ' /~ ~ /// ,,~ ) . ~/. / / 12. Permit can be issued without administmtive approvai .... .~'"N-~ '~ (" ~D~'~z,/~'"~,.'2 ( ~"~/~ /(_/'/"~. ,~ ~ 13. Can permit be approved before 15-daywaiL ........ (. Y )N ./_~, __ ' - - / 14. Conductor string provided ..........f~N 15. Surface casing protects ail ~)~r; ~l~s' ' ' ' ' ' ' ' ' ' 'CYAN 16. CMT vol adequate to circulate on conductor & surf csg . . . ~ N 17. CMT vol adequate to tie-in long string to surf csg ...... 18. CMT will cover ail known producffve hodzons ......... (,~ N 19. Casing designs adequate for C, T, B & permafrost. ..... ~ N _ 20. Adequate tankage or reserve pit. ............... Y(_~/N 21. If a re-drill, has a 10-403 for abndnmnt been approved .... -Y--N"/~' 22. Adequate wellbore separation proposed ............ (Y(Y(Y(~N 2~. I~ dive,er ~equired, i, it adequ,te ................ 24. Drilling fluid program schematic & equip list adequate .... .~N / 25. BOPEs adequate ........................ f,.~N APPR DAT,,E ~,~ 26. BOPE press rating adequate; test to ,~ C, pslg.~ N '"3 ~ . ~, ~.,. %.~ ~?~:, 27. Choke manifold complies w/APl RP-53 (IV~ay 84) ....... ~-- 28. Work will occur wibhout operation shutclown .......... _/~.,.~ , 29. Is presence of H2S gas pmbabl.e. .... .....,. ..... ,~ ¥ Y ~ , ~?~-.-,- , . , ._ , //// ' . .,A' ' ~ ' 31. Data presented on P°tenlJa~ ove"rpress"re z°nes '-..... ~ / ///~, GEOLOGY: ENGINEERING: COMMISSION: RP,C~. ,~ BEW ~'t/z~ DW~ JDHd~ .<~ JDN TAB~ Comments/Instructions: "- - A,%COR~ist rev ,Ug6