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Home My WebLink About199-018Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. 1 -~ ~- -~ -~ ~ Well History File Identifier RESCAN GrlOr items: yscale items: [] Poor Quality Originals: o Other: DIGITAL DATA O Diskettes, No. [] Other, No/Type OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) D Logs of various kinds TOTAL PAGES: ~ ¢ ORGANIZED BY: BEVERLY NOTES: BREN~ SHERYL MARIA LOWELL Project Proofing BEVERLY BREN ~T SHERYL MARIA LOWELL PROOFED BY: [] Other Staff Proof Date: -,s, ¢.¢¢ Scanned (done) SCANNED BY~ (at-the time of scanning) BEVERLY B R ~'/~lN~C E N~HERYL MARIA LOWELL DATE ReScanned (done) RESCANNEDBY~ BEVERLY BREN VINCENT SHERYOLOWELL DATE General Notes or Comments about th~s file: PAGES: Quality Checked Rev 1NOTScenned.w1~ Memorandum State of Alaska Oil and Gas Conservation Commission Cancelled or Expired Permit Action Re: EXAMPLE' Point McIntyre P2-36AXX API# 029-22801-95 This memo will remain at the front of the subject well file. 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 in the treatment of these kinds of applications for permit to drill. 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 remain unchanged. The APl number and in some instances the well name reflect the number of preexisting redrills and or multilaterals 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 drill. The APl number for this cancelled or expired permit is modified so the eleven and twelfth digits is -95. The well number for a cancelled or expired permit is modified with an appended XX. CANCELED PERMITS ARE RELEASABLE 2 years from the date on the letter received from the operator requesting the permit canceled.. (Memorandum January 23, 1997 by Dave Johnston, subject: Canceled and Expired Permits) EXPIRED PERMITS ARE RELEASABLE 2 years from the date on the application was issued by the commission, unless the operator ask for extended confidentiality. AOGCC database has been changed to reflect these changes to this permit. Steve McMains Statistical Technician Re: 2T-218 Permit To Drill Subject: Re: 2T-218 Permit To Drill Date: Thu, 27 Apr 2000 08:11:21 -0900 From: "Thomas A Brockway" <TBROCKW~mail.aai.arco.com> To: Blair Wondzell <blair_wondzell~admin.state.ak.us> CC: "Chip Alvord" <CALVORD@mail.aai.arco.com> Blair, Yes. Please cancel PTD 99-018 as per the discussion below. Thanks, Tom Blair Wondzell <blair wondzell@admin.state.ak.us> on 04/26/2000 09:03:10 AM To: Thomas A Brockway/AAI/ARCO cc: howard okland@admin.state.ak.us, steve mcmains@admin.state.ak.us, Chip Alvord/AAI/ARCO Subject: Re: 2T-218 Permit To Drill Tom, Has PTD 99-018 been canceled? Blair Thomas A Brockway wrote: > Dear Blair, > > There has recently been some confusion over the permit to drill for Tabasco well > 2T-218 located in the Kuparuk River Unit. Back in February 1999, a Tabasco > injector well was originally planned out of this surface slot and a permit to > drill was submitted and approved for this plan (Permit # 99-18). However, the > well was never drilled and in April 2000 a new permit was submitted and approved > (Permit # 200-45) for a production well to be drilled from the same surface slot > but with a different bottom hole location from the previous permit. Permit > #200-45 is the correct permit to use and should replace Permit #99-18 in your > well files. I hope that this helps to clear up any confusion surrounding this > well. If you have any questions or concerns, please don't hesitate to give me a > call. > Thanks, > Tom Brockway > Operations Drilling Engineer > 263-4135 1 of 2 4/27/00 9:47 AM TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 4, 1999 Tom McKay Drilling Team Leader ARCO Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit 2T-218 ARCO Alaska, Inc. Permit No: 99-18 Sur Loc: 768'FSL 556'FWL, SEC. 01, T1 IN, R08E, UM Btmhoic Loc. 821'FSL 1953'FWL, SEC. 36, T12N, R08E, UM Dear Mr. McKav: Enclosed is thc approved application for permit to drill thc above referenced well. Thc permit to drill docs not exempt you from obtaining additional permits required bv lmv from other governmental agencies, and docs not authorize conducting drilling operations until all other required permitting determinations arc made. Blowout prevention equipment (BOPE) must bc tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of thc Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on thc North Slope pager at 659-3607. Robert N. Christenson. P.E. Chairman BY ORDER OF THE COMMISSION dlf/Enclosurcs CC: Department of Fish & Game, Habitat Section w/o cncl. Department of Environmental Conservation w/o cncl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type ofwork: Drill [] Redrill [] I lb. Type ofwell. Exploratory [] Stratigraphic Test [] Developmentoilr-I Re-entry [] Deepen []I Service X Development Gas [] Single Zone [] Multiple Zon,r"l 21 Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. 41 feet 3. Address 6. Property Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-036( ADL 25548 ALK 2662 Tabasco Oil Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 768' FSL, 556' FWL, Sec. 1, T11 N, RSE, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 432' FSL, 1851' FWL, Sec. 36, T12N, R8E, UM 2T-218 #U-630610 At total depth 9. Approximate spud date Amount 821' FSL, 1953' FWL, Sec. 36, T12N, RSE, UM March 7, 1999 $200,000 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 432' @ Target feet 2T-220 19.8' @ 422.7' feet 2560 6809' ' MD / 3306' ' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 250 MD Maximum hole angle 68.5 Maximum surface 1993 At total depth (TVD) 2348 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) 24" 16" 62.5# H-40 Weld 69' 41' 41' 110' 110' 9 cu. Yds. High Early 7.625" 9.875" 29.7# L-80 BTCM 5409' 41' 41' 5450' 2720' 509 sx AS III, 526 sx Class G, 60 sx AS I 6.75" 5.5" x 15.5# L-80 BTCM 6234' 41' 41' 6275' 3040' 169 sx Class G 6.75" 3.5" 9.3# L-80 EUE 8RD 534' 6275' 3040' 6809' 3306' (included above) 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 Cemented Measured depth True Vertical depth Conductor Surface Production ? ~..~ ~ i i~" ;~ Liner Perforation depth: measured true vertical ~ ~ ~u~ ~,~'~ 20. Attachments Filing fee ~ Property Plat ~ BOP Sketch ~ Diverter Sketch ~ Drilling program~ Drilling fluid program Time vs depth plot D Refraction analysis ~ Seabed report ~ 20 ~C 25.050 requirements ~ 21. I hereby certi~ t~e foregoing is true and correct to,the best of my knowledg6 Questions? Carl Tom Brockway 263¢135 Signe - Title: Drilling Team Leader Date ~-- t 7 ~ ~ 7 Tom Mc Kay Prepared by Sharon AIIsup-Drake ~ Commission Use Onl~ , Permit Number I APl number Approval dates~_~~ ISee cover letter ¢~ --~¢ 50- /~ ~ ~ ~ O ~ ~/ Ifor other requirements Conditions of approval Samples required D Yes ~ No Mud Icg required ~ Yes ~ No Hydrogen sulfide me~ures D Yes ~ No Directionalsurvey required ~ Yes ~ No Required working pressure for BOPE ~ 2M; ~~ ~ 5M; ~ loM;D ~ ~1~ ~r ~ ~~~ V Other: by order of ¢~ . Approved by ...... ~ORIG~NAL SIGNED'BY commissioner the commission Date ~ ~ Robert N. Chdstenson Form 10-401 Rev. 12/1/85 · Submit in triplicate Drill, Case aiT~ Completion Plan for Tabasco 2'!~zl 8 (J) Monobore Injector General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. 3. Spud and directionally drill 9-7/8" hole to 7-5/8" surface casing point (+/5450') according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. 5. Run and cement 7-5/8" 29.7# L-80 BTCM casing to surface, displace cement with mud. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. NOTE: TAM Port Collar will be placed in the 7 5/8" casing _+1000' TVD below the surface. Port collar will only be opened and used if cement does not circulate to surface. As an alternative, if observations at surface indicate cement top is above the Port Collar, a top job may be performed in lieu of utilizing the port collar. This is based on the cement thickening time and time required to trip in the hole and open the Port Collar to perform the second stage cement job. Nipple down diverter and install wellhead. Nipple up BOPE and test to 3000 psi. Test casing to 3000 psi. Record results. Pick up 6-3/4" bit and BHA. Trip in and drill out stage collar. Clean out to top of float collar. Shut in BOPs and pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results. Drill out cement and 20' of new hole. Perform formation integrity test, taken to leak off if possible, maximum pressure allowed 16.0 ppg EMW. Drill 6-3/4" hole to well total depth (+/- 6809') according to directional plan, running LWD logging equipment as needed. Run open hole wireline logs as needed. Run and cement a tapered production casing string consisting of 5-1/2" 15.5# L-80 BTCM with a 3- 1/2" 9.3# L-80 EUESRD tail across the Tabasco formation. If needed, pick up 4-3/4" mill tooth bit, 3-1/2" drill collars, and 2-7/8" drill pipe. Clean out to top of 3- 1/2" casing. Pressure test 5-1/2" x 3-1/2" casing string to 3000 psi for 30 minutes. Record results. Swap well over to non-freezing completion brine. Circulate well clean. Trip out. Rig up and run 3-1/2" tubing tieback to surface for monobore injector. Sting into seal bore and pressure test tubing and annulus to 3,000 psi. Set tubing hanger. Install back pressure valve. Nipple down BOP stack. Install production tree and pressure test same. Secure well, release rig. Rig up Coiled Tubing Unit (CTU) and clean out 3-1/2" monobore tubing to PBTD. Circulate well to clean brine. Secure well and release CTU. Rig up E-line unit and RIH with CBL/CET, and run cement bond log across West Sak interval. Report results to office for remedial action if necessary. Rig up E-line unit and RIH with through-tubing perforating guns. Perforate well overbalanced. POOH with perf guns. Repeat runs as required to perforate all desired Tabasco intervals. Rig down E-line unit. Install back pressure valve, shut in and secure well. Page 1 TAB, 02/16/99, v1 . , 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 2T-218 (J) DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, & DRILLING AREA RISKS Well Tabasco 2T-218 (J) Drilling Fluid Properties: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 7-5/8" surface casing 8.5-9.7 16-26 25-50 150-250* 1 O-20 1 O-30 8-15 8-10 4-6% Drill out to TD 9.7 8-15 5-8 70-140 2-4 4-8 8-15 9.5-10 4-7% Drilling Fluid System: Tandem Geolograph/Swaco Shale Shakers Mud Cleaner, Degassers Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 200-250 sec/qt to drill gravel beds Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure is calculated using a surface casing leak-off of 14.1 ppg EMW (0.73 psi/ft) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 1,993 psi. The leak off EMW was chosen based on an open hole FIT on 2%202 taken to 14.1 ppg at 2829' TVD (0.73 psi/ft). Therefore, Arco Alaska, Inc. will test the BOP equipment to 3000 psi. MASP = (3216 ft)(0.73- 0.11) = 1993 psi Based on offset well data, reservoir pressures in the Tabasco sands in the vicinity of 2T pad are expected to be 1450 psi (0.50 psi/ft). Assuming a 100 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.7 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 3074'. Well Proximity Risks: The nearest existing well to 2T-218 is 2T-220. As designed, the minimum distance between the two wells would be 19.8' at 422.7' MD. Drillinq Area Risks: Risks in the 2T-218 drilling area are limited to lost circulation and potential borehole instability in the Tabasco formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous DS 2T drilling results, 9.7 ppg mud should be adequate to control both the West Sak and Tabasco formation pressures without resulting in lost circulation. The 7-5/8" casing shoe will be tested to leak off or a maximum equivalent mud weight of 16.0 ppg upon drilling out of the surface casing. Annular Pum_~in~ Operations: Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well on 2T Pad. (Note that cement rinseate will not be iniected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2T-218 7-5/8" casing annulus will be filled with kill weight brine and diesel after setting the 3-1/2" production tubing string and prior to the drilling rig moving off of the well. Tabasco 2T-218 (J) Injector Completion 16" Conductor @ 80' TAM 7-5/8" Port Collar Collar Stnd. Grade BTC Threads ~i~ (+/-1067' MD / 1000' TVD) 7-5/8" Surface Casing 29.7# L-80 BTCM (+/~ 5450' MD / 2720' TVD) Production Csg. 5-1/2" 15.5# L-80 BTCM run XO/SBE to sudace XO set +/-70' above top perf (+/- 6275' MD) G. 3-t/2" FMC GEN iV tubing hanger 3-1/2" EUE 8RD-Mod pin down F. 3-1/2" L-80 9.3# EUE 8RD-Mod tubing to surface E 3~1/2" x Camco 'KBG-2-9' mandrel w/DV & ~atch, 3-1/2" x 15' ~uDs installed above & ~e~o~ BTCM pin x EUE 8RD-Mod box Soecial Clearance Coupling D, - j[ 3-1/2" L-80 9.3# EUE 8RD-Mod tubing C, 3-- '2" Camco 'DS*{andir ~ n~uole w/2.812" No-Go profile. 3-1/2" x 6' L-80 DUDS ns~al~ec alcove an(] De,ow. EUE 8RD-Mod B. 1 )t 3~1/2" L-80 9,3# EUE 8RD-Mod tubing A, Baker 3-1/2' 'GBH-22' Locator Seal Assembly w/12' of sea~s & Ioca~or 3-1/2" x 6' handhng cue qstsJleQ On top. EUE 8RD-Mod box up r~ Baker xo Coupmg w/~oca~or snouloer, BTC x SBE Baker 5" OD x 4" ID Seal Bore Extension L Bake~ XO SBE x 3-1/2 EUE 8RD 3-1/2' 9.3# L-80 EUE 8RD*Mod run TD to XO/SBE (+/* 6809' MD / 3306! TVD) TAB, 2/16/99, vl Created by:. Andrews For: BROCKWAY Dote plotted: 9-Feb-9~ Plat Raf~rmnom Im 2tS/J Vmmlon ~2. Goordl~atml are tn f~t mt~mn~ mlat ~218. V~I Dmp~m am reference RKB (No~ il0. ARCO Alaska, Inc. Strualure: Pcld 21 Well : 218/J Fleld: Kuporuk River Unlt Loaaflon: North Slope, Alaska East (feet) -> 2400 21 O0 1800 1500 1200 900 600 300 0 300 600 900 1200 1500 1800 21 O0 2400 2700 5000 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 I I I I I I 5700 J TD LOCATION: 821' FSL, 1953' FWL TD - 3506.00 Tvd, 5333.52 N, 1392.35 E t SEC...36, T12N, ReE Base Tabasco - ..3216.00 rvd, 5182.69 N, 1,.352.98 E / Target/Top Tabasco - 3074.00 Tvd, 4944.71 N, 1290.85 E (.,t '1 , Base West Sak Sands - 2668.00 Tvd, 4022.43 N, 1050.08 E // EAST=1291 / 14.63 AZIMUTH - / / Top West Sak Sands - 2192.00 Tvd, 2853.39 N, 744.90 E / / g o.oo o.oo o.oo w 5400 5100 ,*800 4500 4200 3900 3600 3300 3000 I Z o *-I- 2700 2400 2100 1800 1500 120O 9OO 60O 500 500 300 Created by: Andrews For: BROCKWAY Dote plotted: 9-Feb-99 Plot Reference Js 21S/J Version Coordinates ore in feet reference slot ~218. True Vertical Depths are reference RKB (Nordic INTEQ I ARCO Alaska, Inc. J I Structure: Pad 2T Well: 218/J ' J Field: Kuparuk Itlver Unlt Looatlon: Nor'ih Slope, AlaskeJ 300 600 900 1200 1500 1800 2100 2400 2700 5000 3300 5600 5900 500 RKB ELEVATION: 11 1' KOP - 0.00 Inc, 250.00 Md, 250.00 Tvd, 0.00 Vs 5.00 10.00 15.00 DLS: 5.00 dog per 100 ft 20.00 25.00 50.00 35.00 40.00 45.00 50.00 60.00 EOC - 68.50 Inc, 1619.94 Md, 1.316.16 Tvd, 725.88 Vs Base Permafros! - 68.50 In¢, 2096.94 Md, 1491.00 Tvd, 1169.68 Vs Top Ugnu Sands - 68.50 Inc, 24555.2.3 Md, 1615.00 Tvd, 1484.455 Vs 4.63 AZIMUTH o' (,o ***Plane of Proposal*** MAXIMUM ANGLE 68.50 DEG K-155 - 68.50 Inc. 5627.44 Md, 2052.00 Tvd, 25955.65 Vs Top West Sak Sands - 68;50 Inc, 4009.558 Md, 2192.00 Tvd, 2949.01 Vs TARGET ANGLE 60.00 DEG i i i i i i i 0 500 600 900 Bose West Sak Sands - 68.50 Inc, 55507.99 Md, 2668.00 Tvd, 4157.24 Vs 7~/Y'"(~'~ ~''~''j'' ._~cj~?~'/y?.j.),, . Start of Drop - 08.50 Inc, 6012.00 Md, 2926.05 lYd, 481 66 O0 Target/Top Tabasco - 60.00 Inc, 6545.24 Md, 5074.00 Tvd_, 5110.4,3 Vs ~ Base Tabasco - 60.00 Inc, 6629.24 Md, 55216.00 Tvd, 55556.558 Vs ~ TD - 60.00 Inc, 6809.24 Md, 3506.00 Tvd, 5512.27 Vs i I i i i i i i i i i i i i i i i i i i ii i i i i i I i i i i i 1200 1500 1 BOO 21 O0 2400 2700 5000 .5300 55600 5900 4200 4500 4800 51 O0 5400 5700 6000 Vertical Section (feet) -> Azimuth 14.65 with reference 0.00 N, 0.00 F from slot #218 i i i i 6300 6600 Created by: Andrews For: BROCKWAY Date plotted: 9-Feb-99 P~t Refer~nc~ lo 2t8/J Vsralon ~2. ~lno~l ~ In fMt mferen~ slat ~218. T~ V~I~I Dep~l om reference RKB (No.lc III). ARCO Alaska, Inc. Strualure : Pad 2T Well : 21B/J Field : Kuporuk River Unlt Looatlon: North Slope, Alaska I 140 120 1 O0 80 280 26O 240 220 2OO 180 160 140 120 100 80 60 40 20 20 40 6O 120( 2OOO 1001 1000 171 160{ 150C I I I I I I 40 120 1 O0 80 60 1900 1400 1800 700 East (feet) -> 40 20 0 20 40 60 80 I I I / 1700 1 600 '50 3~OO O~ ~ ~-ocr 3001~ / / 3oo~-/"6oc .500- 1600 60O 20 / I r lOOO / I I I t I I ! / I / I / ~ 900 / I / / / / / / / / / ~' 800 / / / / ,{ 1100 / / / / / / / / 3ooe~ / / I / / / I ,~ 800 / 1600 / / / / / / / / / / / 700~' ~ 1000 / v / 7oof / / / / / / / / ~9/~°° / / / / ./8o0 1/400 '00 30// '%00 / / 1 / / / /~00 / / / 0 20 40 60 Easf (feet).-> 8o 100 120 140 160 1BO 500 / / / / / 1300~' / / / / / / / / / / ~ 900 / / / / / / / ~ 1200 / 1900 / / / / 1000=- 1800 / / / / 280 260 240 220 2OO 180 27OO / / / 160 / /'9oo 2000 140 / 120 100 / 80 / 900 60 40 0 3 20 40 60 100 120 140 160 180 /X I Z ~reoted by.' Andrews For: BROCKWAY Dat~ plott~l: 9-F~-99 Plot Refe~ ri 218/J V~n ~2. ~a~l om Tn tnt mfe~ =lot ~216. VI~I De;~e ore ~f~ce RKB (No.lc riO- ARCO Alaska, Inc. Sfruofure: Pad 2T Well : 218/J FTeld : Kuparuk River Unit Lo;orion: North Slope, Alaska A I 200 960 160 120 / 920 ~1900 / I 88o I / I 840 I I I aaa / / 760 ~1800 '1700/ 720 680 :0~ 640 ~ ~oo 600 I 560 520 480 440 400 360 320 280 240 200 80 40 2100 1700 1400 1300 1500 1700 2000 1900 East (feet) -> 0 40 80 120 160 200 I I I I 1800 160 120 80 40 0 4-0 2200 1500 d iI I I I I I I I I I I I 12oo? / / / / / I / ' 1100~ I / / / / / ~/ 1000 100o~ / / / / 80 120 160 East (feet) -> 700 240 280 2500 1200=/ / / / / / 2400 / / / / / / / / // // / 1900 520 560 / 350( / / / / / / / / / / 2000 1 / / / / / t / / / / / 1800 )'11 O0 / / / / / / 1 BO( / / 200 240 280 / / / / / / / 520 ,.560 400 440 g60 g20 880 840 O0 2100 800 760 720 680 /~ 640 120C / 600 / / / 560 / / / 520 480 ~ 440 / / / / 40O / ~1200 / 360 320 / 280 / 240 400 440 Z 0 A I Created by: Andrews ~'or: BROCKI~AY Oete plotted: 9-Feb-g9 Plot Retemn~ il 218/J Veml~ ~2. ~lna~l o~ In fNt ~femn~ ~ot ~218. 2600 2500 2400 2300 2200 2100 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 400 500 200 100 0 I I I I 0 2800 2600 2600 240( 2600 ARCO Alaska, Inc. Struature: Pad 2T Well : 218/J Field : Kuparuk River Unit Location: North Slope. Alaska East (feet) -> 1 O0 200 500 400 500 600 2609 / / / / / / / / ! 2400 ~ / / / / / I 2000 800 400 300 200 100 0 100 2200 260O 3200 / / / 5ooo / / / / / / / / / ~1600 / / / / / / / / / :260© / / / / / / / ~'1800 / / / t / / / / / / / I / ~ ~8oo / / 200 300 400 500 Easf (feet) -> / / / / 44( ,.400/ / / / / / / / / / 2000 700 800 go0 1000 1100 I I I I I // // 5000 800 ¢ 2400~ / / / 4800 / //t : 2800 / // / / / /1600 ~ 2200 / / / / / 2600/ I/ / // / / // 2600 / // / // iiI /11 : j,' 5 16o~ .~ ,1400 // //- '/ II/ II I/ II / // / ~2000 / /:2800 / /600 Ii // // I i/ I / / / ~ 2600 600 700 800 900 1000 11 O0 2600 2500 2400 2500. 2200 2100 2000 1900 18oo I Z o 1700 -'~ 1600 tl) 1500 1400 1500 1200 1100 1000 9OO 800 ~reoted by: Andrews For: BROCKWAY D4t~ plotted: 9-Feb-g9 Plot Rli'erenOe II 218/J V~mlon ~2. V~I ~1 ~m ~fe~nce RKB (~lc Ill), IARCO Alaska, Inc. Struoture: Pud 2T Well : 21B/J Fleld: Kuporuk River Unit Loomflon: NoMh Slope, AIoskm East (feet) -> 600 400 200 0 200 400 600 800 1000 1200 1400 1600 1800 2000 5800 t ~ I i i t I i I i 2200 2400 2600 ~ t I I 5800 4400 5800 5600 5400 5200 4400 5000 4200 560O / / 5600 / / / 5400 / 2800 5200 5000 5400 / ~ 3200 / / 5200 I / 3000 5000 / / / / 4800 / 2800 / / 4800 / # 2600 / 4600 / 4000 4000 / 3800 3800, / / / / 2400 4400 4600 4200 4000 / / / 22o0~ / / / / / / / / / / ~ ~ 2000 / 2200 3400d// // / ;/ 00,~ / 26/ ,/220O / 5200 3200~/f/ / / / / / / / / 3600 ~ ~!l ~ 2600 / II I / II I 3800 4800 / 4600 / / / 4400 / / A / I / 4200 / Z / 0 ~2200 4000 ~ / / ~-~ / ~) 3800m m / 2600 ~ 3600 / / / / / 3600 3600 II I / II I // / / 3400 3400 f 2400 / 3400 / / ;~400 3200 3200 / / / 3400F~1 / 3000 / / 3000 2800 / / 5200 / 5600 ~3200 2800 / -2800 / / / / / ;/3000 2600 ~ / / 3000 2600 3400 / / / ~ / / / 2400 \ J / / 260O 2400 2200 2200 600 400 200 0 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 EaSt (feet) -> Created by: Andrews For: BROCKWAY D~te plott~d: 9-Feb-99 Plot Reference le 218/J Vermlon ~2. Coordlflatel om {fl f~t mfemn~ ~lot ~21B. T~i Vi~l~ OIp~l Om reference RKB (No.lc 320 33O 340 ARCO Alaska, Inc. Struoture: Pad 21 Well : 218/J Field: Kuparuk Rlvir Unit Loaatlon: North Slope, Alaska TRUE NORTH 350 0 10 2O 3O 4O 3OO 310 '"1 ~'0~ 7~01800 60 29O 7O 280 80 270 9O 260 100 250 110 240 / / 230/' 800 / / / 220 / 210 ...-~o "'2 O0 ~. 400 ...o~O~ ~' 1 9 0 ~oo \ \ \ xx x ~1 60 1 70 ~ mo ~ aoo Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Welt 150 120 1000 140 .~re(Ited by: Andrews For: BROCKWAY O~te plotted: 9-Feb-99 Plot Reference il 218/J V~ion ~2. ~Mlno~l om In fMt mferen~ alot ~218. rrna V~}~I Oep~l em reference RKB (~)c HI). 320 330 Alaska, Inc. 340 TRUE NORTH 350 0 10 2O 30 40 310 5O 300 6O 290 7O 28O '8O 270 9O 260 250 240 12( 100 .00 110 120 /~ 1000 / / 2 0 / 2~11000 200 190 ~ 1600 oo Normal Plane Travelling Cylinder- Feet All depths shown are Measured depths on Reference Well 160 \ 130 140 1200 % 10~q,. 1300 :reoted by: Andrews For: BROCKWAY O~ plotted: O-F~b-gO Plot Reflren=e r. 218/J Ve~lon ~2. ~o~g ~ Tn f~t ~eren~ .~t ~2t6. r~. Vl~l~l Olp~l O~ rlfe~cl RKB (No.lc 520 330 ARCO Alaska, Inc. Sirualure: Pod 2T Well : 218/J Field: Kuparuk River Unit Loaatlon : Norfh Slope, Alaska 340 TRUE NORTH 350 0 10 20 3O 40 510 50 3O0 290 6O 7O 280 1 )0 80 270 1 90 260 100 250 40 4250 750 23O (;D~l'~-~5o~ 2 0 21 0 3000 2500 ~o~-- 190 180 2750 ..L~oo 150 3000 ~ 3000 _ 3250 ~0 3500 170 110 120 5250 ~. 550p30 ~ 5750 2500~, ~000 140625~s° Normal Plane Travelling Cylinder- Feet All depths shown ore Measured depths on ReferenCe Well ARCO Alaska, Inc. Pad 2T 218/J slot #218 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE by Baker Hughes INTEQ REPORT Your ref : 218/J Version#2 Our ref : prop3086 License : Date printed : 9-Feb-99 Date created : 28-Jul-98 Last revised : 9-Feb-99 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.172,w150 0 47.034 Slot location is n70 19 52.725,w150 0 30.800 Slot Grid coordinates are N 5970748.059, E 498945.215 Slot local coordinates are 768.00 N 556.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <4135-4496'>,,207,Pad 2T PMSS <1664-4645'>,.220PB2,Pad 2T PMSS <O-2140'>,,220PB1,Pad 2T PMSS <853-4995'>,,220,Pad 2T PMSS <0-4472 Depth Shifted N3>,,215,Pad 2T PMSS <0-4082' Depth Shifted NIII>,,2og,Pad 2T PMSS <O-9298'>,,27,Pad 2T PMSS <0-5340'>,,210,Pad 2T PMSS <918' - 10890'>,,28,Pad 2T PMSS <0-9845'>,,19,Pad 2T PMSS <469-10632'>,,18,Pad 2T PMSS <893 - 12977'>,,23,Pad 2T PGMS <O-7897'>,,3,Pad 2T PMSS <0-4175'>,,201,Pad 2T PMSS <918 - 10193'>,,22,Pad 2T PMSS <741-15471'>,,36,Pad 2T PMSS <0 - 9210'>,,26,Pad 2T PMSS <O-12821'>,,21,Pad 2T PMSS <921-10235'>,,20,Pad 2T PMSS <650 - 11080'>,,37,Pad 2T PGMS <O-8262'>,,14,Pad 2T PGMS <O-7625'>,,15,Pad 2T PMSS <1604-3625'>,,16,Pad 2T PGMS <0-8947'>,,16B,Pad 2T PMSS <5917-7957'>,,16A,Pad 2T PGMS <0-7650'>,,8,Pad 2T PGMS <0-8250'>,,lO,Pad 2T Closest approach with 3-D Minimum Distance method Last revised Distance M.D. 5-Feb-99 135.1 277.3 3-Feb-99 19.8 422.7 3-Feb-g9 19.8 422.7 3-Feb-99 19.8 422.7 5-Jan~99 38.6 259.1 30-Dec-98 112.8 250.0 23-Jan-98 275.8 250.0 4-Dec-98 101.0 80.0 23-Jan-98 261.0 250.0 23-Jan-98 820.8 250.0 21-0ct-98 803.9 268.2 25-Aug-98 336.0 100.0 26-Aug-98 390.9 250.0 26-Aug-98 528.5 100.0 23-Jan-98 351.0 100.0 23-Jan-98 753.0 100.0 23-Jan-98 290.9 250.0 23-Jan-98 850.9 180.0 23-Jan-98 836.0 100.0 23-Jan-98 864.7 277.3 23-Jan-98 715.0 259.1 23-Jan-98 741.0 0.0 23-Jan-98 766.0 0.0 23-Jan-98 766.0 0.0 23-Jan-98 766.0 0.0 23-Jan-98 .516.0 0.0 23~Jan-98 616.0 100.0 Diverging from M.D. 277.3 422.7 422.7 422.7 259 1 25O 0 250 0 8O 0 6809 2 250 0 268 2 100 0 250 0 100 0 100 0 100 0 250.0 180.0 100.0 277.3 259.1 0.0 0.0 0.0 0.0 0.0 100.0 PMSS <380 - 11400'>,,31,Pad PMSS <O-10570'>,,29,Pad 2~ PGMS <O-8890'>,,2A,Pad 2T PMSS <1287-1725'>,,2,Pad 2T PMSS <4757-6800'>,,12A,Pad 2T PGMS <0-6725'>,,12B,Pad 2T PMSS <3115 - 3645'>,,12,Pad 2T PGMS <0-6789'>, PGMS <0-7868'>, PGMS <0-8445'>, PGMS <0-8160'>. PGMS <0-7670'> PGMS <0-8208'> PGMS <0-6975'> PGMS <0-6370'>. 11,Pad 2T 13,Pad 2T 17 Pad 2T ,4 Pad 2T ,5 Pad 2T ,6 Pad 2T ,7 Pad 2T ,9 Pad 2T PMSS <12144-13360'>,,38A,Pad 2T PMSS <4627 - 10686'>,,30A,Pad 2T PMSS <0-4749'>,,30,Pad 2T PMSS <5497-13787'>,,32B,Pad 2T PMSS <0-5924'>,,32,Pad 2T PMSS <4850 - 5918'>,,32A,Pad 2T MSS <4046-4427'>,,202,Pad 2T 23-Jan-98 23-Jan-98 26-Aug-98 26-Aug-98 23-Jan-98 23-2an-98 23-~an-98 23-~an-98 23-~an-98 23-Jan-98 23-~an-98 23-Jan-98 23-~an-98 23-Jan-98 23-~an-98 23-Jan-g8 16-~ul-98 16-~ul-98 24-Feb-98 24-Feb-98 24-Feb-98 26-Aug-98 212.4 246.0 366.0 366.0 665.2 665.2 665.2 640.9 691.0 790.9 415.6 440.3 464.6 491.0 540.9 703.0 228.8 228.8 201.0 201.0 201.0 321.0 300. 100. O. O. 259. 259 259 25O 0 140 25O 259 268 0 180 100 268 268 0 0 0 100 ~L~i 300.0 100.0 250.0 250.0 259.1 259.1 259.1 250.0 0.0 140.0 250.0 .259.1 268.2 0.0 180.0 100.0 268.2 268.2 0.0 0.0 0.0 100.0 7-1/16" 50r psi BOP Stack-- Nordic Rig 3 Kuparuk River Unit Tabasco Operations -Injector Wells Kill Line 4 3 I Choke Line Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. BOP Stack Test 1. Fill BOP stack and manifold with water. 2. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi Iow and 3000 psi high. Test as in step 4. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi and 3000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 250 psi Iow and 3000 psi high for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 3000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with BOP test pump. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. 1. 16" Starting Head 2. 7-1/16" 5000 psi Tubing Head 3. 7-1/16" 5000 psi Hydril Single Pipe Rams, 3-1/8" 5000 psi Side Outlets w/ Manual Locks 4. 7-1/16" 5000 psi Drilling Spool with Choke and Kill Lines, 2 Choke valves - one 3" 5000 psi Hydraulic gate and one 3" 5000 psi Manual gate, 2 Kill valves - each are 3" 5000 psi gate 5. 7-1/16" 5000 psi Hydril Double Ram with Pipe Rams on Top and Blind Rams on Bottom, 3-1/8" Side Outlets w/Manual Locks 6. 7-1/16" 5000 psi Hydril Annular Preventer, Hub Bottom Connection TAB, 10/01/98, v.2 16" DIVE_¥ER SCHEMATIC - Nc~Jic Rig 3 Kuparuk River Unit Tabasco Operations Open --~ I Closed __..~ · To Accumulator I I I ~_ .... From Accumulator Open Maintenance & Operation 1. Upon initial installation: - Close valve and fill preventer with water to ensure no leaks - Close preventer to verify operation and that the valve opens immediately 2. Close annular preventer in the event that an influx of wellbore fluids or gas is detected. Open valve to achieve diversion DO NOT SHUT-IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES 1. 16" Conductor 2. 16-3/4" 2000 psi Slip-on Weld Starting Head (Quick Connect) 3. 16-3/4" x 21-1/4" 2000 psi, Double-Studded Adapter Flange 4. 16" Diverter Spool with APl 21-1/4" 2000 psi Flanges 5. 21-1/4" x 13-5/8" 5000 psi, Double Studded Adapter Flange 6. 13-5/8" Hydril GK 5000 psi Annular Preventer 7. 16" Knife Valve. The valve opens automatically upon closure of annular preventer. 8. 16" Diverter Line TAB, 07/29/98, v.1 1 ]9/16/98 MRT JM PER K~.,.. K98075ACS ~ T II N i o ~2o ~o. 37.5' --~<) 215 ~ .~. ,. 62.5' i . m -o 210 o · ~o ~CINI~ MAP · 29 · 28 ,,, · 27 SEE SHEET 2 FOR NOTES AND · 26 LOCATION INFORMATION · 202 · 23 · 22 ; · 2 i · 6 20lC 8 · 9 · IO · 12 , 38ee 13 ~ · 14 (NO SCALE) 2 1 · 15 ~ .... 36 · , 11 ~12 · 17 i e 18 D~ILL SITE ~ · ~9 e 2o 2-T ~ · 37 LEGEND mmm , [x~s~ co~aucm~s LOUNSBUR ~5[ ~ ~ssoc~a,~s, ~c. ~ DRILL SITE 2-T Alaska, Ino. C0 0UClORS 207-2~0,2~5,218 220 Subsidiary of Atlantic Richfield Company AS-BUILT LOCA~ON CADO FILE NO. ) IDRA. NC NO: I SHEET: LK622012 9/16/98 CEA-D2~-6220D12 ool OF 2 9/16/98J MRT JM PER KS~w~.~.K98075ACS NO~S ,,~.~~ 2-T MONUMENTS PER LHD ~ ASSOCIATES. ~ C ~ ALL DISTANCES ARE TRUE. " E~ ~ ~ 5. ELEVATIONS SHO~ ARE B.P.M.S.L. ~L / 4. WELLS ARE LOCATED ~THI" PROTEACTEO SECTION 1, ~~'~~~ T. 11 N., R. 8 E., UMIAT MERIDIAN, ALASKA. 5. DATE OF SURLY: 9/13/98, FIELD BK. L98-71 pg. 14-23. 6. DRILL SITE 2-T ORID NORTH IS ROTATED 179' 59' 40" ~ST FROM A.S.P. ZONE 4 GRID NOR~. 7. SEE REFERENCE DRAWINGS: CEA-D2TX-866, FOR CONDUCTOR 2-17 LOCATIONS, CEA-D2~-6220D7 FOR CONDUCTOR 18-23, ~CINI~ MAP ~--2 a~L~S 26-32, 36-38 · TABASCO LOCATIONS, AND CEA-D2TX-6220D9 FOR CONDUCTOR 202. LOCA~D IN SEC~ON 1, T 11 N, R 8 E, U.M. SEC. SEC. ~ i ~LL LINE LINE O.G. PAD NO. Y X LATITUOE LONGITUDE O/S O/S ELEV. ELEV. I F.S.L F.W.L. , . 207 ~ 5,970,610.10 4.~8,945.02 70'19'51.368" 150'00'30.805" 650' 556' 75.2' B0.4' I , , i 208 5,970,622.69 498,944.87 70~ 9'51.492" = 150'00'30.810" 642' ~ 556' 75.2' 80.4' , 209 5,970,635.10 498,944.90 70~9'51.614" 150~0'50.809" 655' 556' 74.9' 80.4' 210 5,970,647.69 498,944.73 70'19'51.758" 150'00'30.814" 667' 556' 74.7' 80.4' , 215 5,970,709.72 498,944.99 70'19'52.548" 150'00'30.807" 729' 556' 74.2' 80.4' , 218 5,970,747.74 4~8,944.97 70-19'52.722" 150'00'30.807" 768' 556' 74.1' ~ B0.4' 220 5,970,772.57 498,944.90 70'19'52.966" 150'00'30.810" ' 792' 556' 74.1' 80.4' · ~Lq~ .......... .~ ~e. SUR~YOR'S CERTIFICA ~ ~." ~ ".._~A I HEREBY CERTIFY THAT I ~ PROPERLY REGISTERED AND ~ ~ ~ ~ ~ LICENSED TO PRACTICE LAND SU~VEY/NG /N THE STARE OF ~ : 49~h ~ ~t ~- ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY ..... ~' ........... ~ ..... ~ OONE BY ME O~ UNDER MY DIRECT SUPERVISION AND ~,~E AsTHAToFALLsEPTEMBERDIMENSIONS16. ANDi998.0THE~ DETAILS ARE CORRECT AREA: 2l ~ODULE: XX UNIT: D2 2-T ARCO Alaska, Inc. ~LL CONDUCtoRS 207-210,215,218 A 220 Subsidiery of Atlontic Richfield Compony AS-BUILT LOCA~ON ,, LK622012 9/16/98 CEA-D2TX-6220D12 002 OF 2 SEC. SEC. WELL LINE LINE O.G. PAD NO. Y X LATITUDE LONGITUDE O/S O/S ELEV. ELEV. F.S.L F.W.L. 207 5,970,610.10 4...98,945.02 70'19'51.,:368" 150'00'30.805" 6.:30' 556' 75.2' 80.4' 208 5,970,622.69 498,944.87 70'19'51.492" 150'00'30.810" 642' 556' 75.2' 80.4' 209 5,970,635.10 498,944.90 70'19'51.614" 150'00'.:30.809" 655' 556' 74.9' 80.4' 210 5,970,647.69 498,944.73 70'19'51.758" 150'00'30.814" 667' 556' 74.7' 80.4' 215 5,970,709.72 498,944.99 70'19'52.548" 150'00'30.807" 729' 556' 74.2' 80.4' 218 5,970,747.74 4.98,944.97 70-19'52.722" 150'00'30.807" 768' 556' 74.1' 80.4' 220 5,970,772.57 498,944.90 70'19'52.966" 150'00'30.810" 792' 556' 74.1' 80.4' ARCO Alaska, Inc. AAI Drilling Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Drilling Manager February 16, 1999 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill Tabasco 2T-218 Tabasco Injector, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore production well to the prospective Tabasco interval from 2T Pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the Tabasco sands in the vicinity of 2T pad. The well is designed as a monobore injection well using a 5-1/2" x 3-1/2" tapered casing string, a seal bore, and 3-1/2" tubing used as a tieback string. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1 ) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). Note that due to the pressures expected in the Tabasco sands, ARCO proposes to test the 5000 psi BOP equipment to a maximum of 3000 psi, pending AOGCC approval per this letter and APD. Please note that due to the large number of KRU wells which have penetrated the Tabasco sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at 2T-218, such as shallow gas. 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program is attached. 9) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S and combustible gas monitoring equipment functioning on the rig as is the standard operating procedure in the Kuparuk River Unit drilling operation. 10) Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. Please note that the anticipated spud date for this well is March 7, 1999. If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or Paul Mazzolini at (907) 263-4603. Sincerely~~ Thomas A. Brockway ~ Operations Drilling Engineer Attachments: CC: Tabasco 2T-218 Well File Paul Mazzolini ATO-1066 Jack Walker ATO-1200 Larry Gipson ATO-1146 Lewis Ledlow ATO-1063 ARCO Alaska, Inc. 73-42~ 839 AAI PAYABLES ~.o. ~ox ~o~6 .,', ;~,..~~--,205087846 Anchorage, AK 99510-2776 ~'~'~ i:: ( ~.~. ~, t,!' '!~ ~.i 0997579 JANUARY 19, 1999 TO THE .... ~,;.! .1 ORDER OF: ALASKA DEPT OF REVENUE '~::'-:: ALASKA OIL & ~GAS' CONSERVATION COMMI ~? ;i,.';f~ 3001 PORCUPINE: DRIVE : , ~,;. J,,: t': ..... t?~i'.~:.:',... D: ~:FTFR 90 DAYS : :..~ i" i! ":" '::" ! .... .:.-':..::~:i-~-:?, ..;?:.: .:. :." .... ' :i: ' . ,: ': ::: ' ::' EXACTLY ***********i100 DO~s AND O0 CENTS $**********.100.00 The First National Bank:of Chicag°-0710 '::..~ ::~!;: -:.::. Payable ThroUgh'Republic Bank : Shelbyville, Kentucky TRACE NUMBER: 205087846 ," ;~O 506 ? P. ~, r-.,. ~:OP. ~ c~o h ii ~, ;~,: O cl c~ ? c; ? cf,. , WELL PERMIT CHECKLIST COMPANY ~'~ ~ ~ WELL NAME 7~"/~. -2--7- '~ ? ~ PROGRAM: exp ~dev ~ redrll ~ serv ~wellbore seg ann. disposal para req ~ FIELD & POOL INIT CLASS 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 ddlling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in ddlling 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 ........... ENGINEERING APPR DATE 14. Conductor stdng provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to __;~(:3OC~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY GEOL AREA N N (~N (~N (~N (33N qgU APPR D T ANNULAR DISPOSAL APPR DATE 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... Y 32. Seismic analysis of shallow gas zones ............. , 33. Seabed condition survey (if off-shore) ............. ' '" 34. Contact name/phone for weekly progress repods [exploratory one] Y N 35. With proper cementing records, this pl~)~1~ j/ A ) ~ (A) will contain waste in a suitable re/~iving ~l~ne; ....... ! v ,., Y N (B) will not contaminate freshwaterJor cause' drilling waste... P-.-~.~ z i. Y N to surface; /' / '~. ~/Z.,~y (C) will not impair mechanical i~legrity o~he well used for disposal; ;3 I,,P ~Jf Y~ U (D) will not damage produci~ formation'or imp'~- :~-air recovery from a '-' --'1 ~ N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N UNIT# //1~'~ ON/OFF SHORE GEOLOGY: ENGINEERI~IG: UlC/An~(~iar JDH ~ COMMISSION: DWJ ~ RNC co Comments/Instructions: © O c:\msoffice\wordian\diana\checklist