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Home My WebLink About193-163 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. NumberH,s,o PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by:~iann~ ~ncent TO RE-SCAN Notes: Nathan Lowell Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: Is~ Memorandum State of Alaska Oil and Gas Conservation Commission Re: Cancelled or Expired Permit Action EXAMPLE: Point McIntyre P2-36AXX API# 029-22801-95 ,,q u. j BI, t This memo will remain at the front of the subject well file. Our adopted conventions for assigning AP! 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 AP! number and in some instances the well name reflect the number of preexisting reddlls and or muitilaterats 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 ddll. The AP! number for this cancelled or expired permit is modified so the eleven and twelfth digits is 95. The well name for a cancelled or expired permit is modified with an appended xx. These procedures are an addendum to the APl numbenng methods described in AOGCC staff memorandum "Multi-lateral (weilbore segment) Drilling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician Sep. 26. !995 !I:I?AM AP, C~.ALASKA INC ARCO Alaska, Jnc. Post Oftice Box 100350 Anchorage. Alaska 99510-0360 Telephone* 907 276 1215 Septembe~ 26,1995 No. 3533 P. 2/2 Steve McM~ Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive A~chorage, AK 99501 Sub. ject: CanceUation of Approved Permits to Drill for Undrilled Wells Dear Mr. MctVf~s: Per our discussion last week, I ~rt writing to request that you cancel several approved Permits to Drill for the Kuparuk River Unit The wells were pem~tted for -' different expazusion ~nd infill projects during the last two years. Due to inforrrmtion -. gained from other new wells or to changes in the drilling schedule, ~e wells I'd l~ke to cancel were dropped from the program. While we wilI reuse the well naznes, by the time ~e wells are actually drilled the information will be significantly differ~t than is on the current approved permits. Since this change requires re-submission of : . a Form 401 anyway, I think it wouId be easier on both of us to cancel the current permits. _ rd to cancel the Pemits to Drm for the following wells: ct3- l~8 KRU~.-04 q3- IU5 ~U2E-18 ~U ~-18 (Petit ~166~ ~sue date 1~/9/93) ~U ~-~ ~e~t ~]63~ ~sue date ~0/27/93) KF, U 3M-27 ICRU 3H-24 KRU 3H-29 ' KRU 3H-30 2A-t8 and 2A-22 inadvertently have two Permits to Drill, each; please cancel only the permit noted abov. Thank you for calling our attention to this matter. If you have arty questions on the above wells please call me, Sincerely, ' Denise Petrash Drilling Engineer I. t-Iartz M. Zangki S. Allsup-Drake (W1) Well File AOGCC (Anchorage) ATO-1286 ATO-I205 S EP 2 G 1995 Gas Cons. Commission Anchorage ATO-1205/ATO-370 (one copy f/each well listed above) AR38-6003-93 242-2503 ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Januaw 10,1994 Phyllis Billingsley ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Dear Ms Billingsley: The Commission is compiling statewide drilling statistics for 1993. Attached is a list of outstanding Permits to Drill issued to your engineering group (permits for which no form 10-407 has been received by this office). Please review this list to determine if any of the wells were drilled in 1993. If so, please note the well name, total measured depth, and class (development, service or exploratory). If any wells were drilling as of 12/31/93, estimate the depth at 12:00 midnight. We would appreciate your reply by the end of January if possible. Thank you for your cooperation with this project. If I may be of any assistance, please call me at 279-1433. Yours very truly, Robed P Crandall Sr Petr Geologist encl jo/A:RPC:\drlstats 1/04/94 OPERATOR ARCO ALASKA ARCO ALASKA INC ARCO ALASKA ARCO ALASKA ARCO ALASKA ARCO ALASKA ARCO ALASKA ARCO ALASKA ARCO ALAS~A ~NC ARCO ALASKA ARCO ALASKA ARCO ALASKA ARCO ALASKA ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA INC ALASKA WELLS BY ARCO PERMIT 93-0166-0 93-0152-0 93-0151-0 · 93-0163-0 93-0144-0 93-0188-0 93-0179-0 93-0169-0 93-0104-0 93-0189-0 93-0174-0 93-0175-0 93-0187-0 93-0195-0 93-0196-0 93-0193-0 92-0040-0 WELL NAME KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UI~IT KUPARUK RIV U~IT KUPARUK RIV UNIT KUPARUK RIV I/NIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KI3PARUK RIV UNIT 2A-18 2A-19 2A-20 2A-22 2A-24 2E- 04 2E- 05 2E- 06 2E-07 2E-08 2E-17 2E-18 3M-23 3M-24 3M-25 3M-26 3R-16 ALASKA OIL AND GAS CONSERVATION COMMISSION October 27, 1993 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 A. W. McBride Area Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 . Re: Kuparuk River Unit 2A-22 ARCO Alaska, Inc. Permit No: 93-163 Sur. Loc. 756'FSL, 227'FWL, Sec. 13, TllN, R8E, UM Btmhole Loc. 2438'FNL, 380'FWL, Sec. 13, TllN, R8E, UM Dear Mr. McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. e Chair~~ BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. * STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type ol Work Drill X Redrill [] lb Type of Well Exploratory [] Stratigraphic [] Development Oil X Test Re-Entry D Deepen D Service [--] Development Gas r"] Single Zone X Multiple Zone i--I 2.. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 135', Pad 94' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25570, ALK 2668 4. Location of well at sudace 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 756' FSL, 227' FWL, SEC. 13, T11N, RSE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 2706' FNL, 360' FWL, Sec. 13, T11N, R8E, UM 2A-22 #U-630610 At total depth 9. Approximate spud date Amount 2438' FNL, 380' FWL, Sec. 13, T11N, R8E, UM 10/28/93 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in properly 15. Proposed depth (MD and TVD) property line 2A-01 6940' MD 2706' @ TD feet 23.6' @ 1800' MD' feet 2560 6219' TVD feel 16. To be completed for deviated wells 17. Antic. ipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 3100 feet Maximum hole angle 41.02° Maximum surface 1687 psig At total depth (TVD) 3197 pslg 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24' 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 12.25' 9.625' 36.0# J-55 BTC 2809' 41' 41' 2850' 2850' 290 Sx Arcticset III & HF-ERW 380 Sx Class G 8.5" 7' 26.0# L-80 BTCMOE: 6899' 41' 41' 6940' 6219' 170SxClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured dfl~th r~, ~,,T~e, ~(e ~i~l ~l[~pth Structural N L :IV Conductor _ ~.- ~.~ Surface Intermediate Production0 CT 1 9 199, Liner Perforation depth: measured Alaska 0it & Gas ~UR$, bu(itr!~.isst( true vertical Anchorage 20. Attachments Filing fee X Property plat E] BoP Sketch X Diverler Sketch X Drilling program X Drilling fluid program X Time vs depth plot E] Refraction analysis E] Seabed report [-~ 20 AAC 25.05O requiremenls X 21. I hereby-o~e_rtify that~he foregoing is true and correct to the best of my knowledge Signed~,~.{_~~' ~ ~./,,~ /I//c/~/F_/~'~ Title Area Drillinc, l Engineer Date ,o/,'1, /¢/-~ v Commission Use Only Permit Number I APl number i ^~,~? ~., I See cover letter lor ~ -/~,~ 50-/'~)~ - ~ ~//~<~ '~ other requirements Conditions of approval Samples required ~ Yes ,~] No Mud log required D Yes ,~ No Hydrogen sulfide E] Yes 12~ No Directional survey required .,~ Yes D No measures Required working pressure for BOPE E] 2M r"] 3M ~ 5M E] 10M ~'1 15M Other: Origina! $!cn-~d.:. ,~ ~Jy by order of Approved by David W. ~h'-'~-~ ' _ _ . ,~, .... ~[On Commissioner the commission Date / ~/~'Tf~ ~ Form 10-401 Rev. 7-24-89 iplicate .iOreated by : jones For: M ELLIS iDate plotted : 29-Sep-93 iPIot Reference is 22 Version //.3. iCoordinotes ore in feet reference slot #29. True Vertical Depths are reference wellhead. --- Baker Hughes INTEQ i 25O 500 750 1000 1250 ~ 1750[ 2250~ 2500] 2750] .3250~ 3750~ 4000_ 4250] 4500_ RKB ELEVAllON: 135' lB/ PERMAFROST l'VD=1495 T/ UONU SNDS TVD=1645 T/ W SAK SNDS TVD=2245 B/ W SAK SNDS TVD=2745 9 5/8" CSG PT 1~/D=2945 I<OP TVD=3100 TMD=3100 DEP=O ,3.00 K-lO TVD=5210 TMD=3210 DEP=3 9.00 15.00 21.00 SU~LD 5 DEG/ 100' x~27.00 ~k~C33'00 9.00 EOC TVD=4353 TMD=4467 OEP=469 K-5 ~/D=4465 TMD=4615 DEP=566 A[ CO ALASKA, Structure : Pad 2A Field : Kuparuk River Unit Well: 22 Location : North Slope, Alaska 5250_ _ .5500 _ 6250_ I I 0 250 Scale 1 : 125.00 TD LOCATION: 2438' FNL, 380' SEC. 13, T11N, RBE TARGET LOCATION: 2706' FHL 360' FWL SEC. i.3, T11N, RSE : TARGET TVD=5910 TMD=6550 DEP=1825 HORTH I818 E~ST 133 N 4.18 DEG E i823' (TO TARGET) AVERAGE ANGLE 41.02 DEG ~TARGET TVD=5910 TMD=6530 DEP=1823 ~B/ KUP SNOS TVD=6068 TMD=6740 DEP=1960 TD / 7" CSG PT TVD=B219 TMD=6940 DEP=2092 I I I I I t I I I I I I I i / 500 750 1000 1250 1500 1750 2000 2250 Vedicel Section on 4.18 azimuth wilh reference 0.00 ti, O.OO E from slot ~22 ........ East --> 100 0 100 20'0 300 400 I ~l~..~..~,xl 1~ - 2200 _2100 _2000 _ 1800 _ 1700 ~x..~_~. ~ _ 16~d / _ 1000 Z 0 _ _ 900 ~ 8OO 1 O0 -- (b 0 " ~00 rD SURFACE LOCATIOH: 756' FSL, 227' FWL SEC. 13, T1 IH,..~RSE. I RECEiV 00!" 1 9 199 Alaska Oil & Gas Cons. c0mmissioO Anchorage Scale 1 · 50.00 50 1 O0 150 I I I I I. Eas 200 I I I iiiiIi 250 I 300 350 I I 400 I 45O 1100 ~RCO ALASKA, Inc. 4OOO 24OO 14OO 1050 IOO0 95O 380O 36O0 '00 900 ~5o I 800 3000 1600 3600 O0 ,3800 75o 7 0 700 ~_ 650 looo 4000 4200 6OO _ 550 _ 500 _ 450 I . . . . . , . . . 10. 11. 12. 13. 14. 15. 16. 17. 18. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 2A-22 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (2850')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (6940') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) Pressure test to 3500 psi. ND BOPE. NU tubinghead & full opening valve for cased hole logging. Secure well and release rig. Run cased hole cement evaluation. ND full opening valve & NU tree assembly. Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. & Gas Cons. commission Anchorage DRILLING FLUID PROGRAM Well 2A-22 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-80* 5-15 15-40 10-12 9.5-10 _+10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Weight up to TD 10.8 10-18 8-12 35-50 2-4 4-8 4-5 thru Kuparuk 9.5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1687 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 2A-22 is 2A-01. As designed, the minimum distance between the two wells would be 23.6' @ 1800' MD. The wells would diverge from that point. 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 the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 225 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. 9C-!' I t~ t99;~ &laska 0~1 & uas L;ons. Commissio¢ Anchorage Casing Design / Cement Calculations 18-Oct-93 Well Number: Surface Csg MD: Surface Csg TVD: Production Csg MD: Production Csg TVD: Top of West Sak, TMD: 'Top of Target, TMD: Top of Target, TVD: Estimated Pressure: Surface Casing Choice: Production Csg Choice: Production Casing Frac. Pressure 2A-22 2,850 ft 2,850 ft 6,94O ft 6,219 ft 2,245 ft 6,530 ft 5,910 ft 3180 psi :.-.::;::::;:: :::::::::::::::::::: ::!: ::::::::::::::::::::::::::::::::::::::::: . * .. ............ :-: ........... :. ¢;. ¢ :.:.:.:.:.:.:.:.:.;.;.;.;-...;.;.;.;.,.. ¢ ¢:-;...,;.;.;.¢ :. ¢: I.~.i~i~!.::.~.i.i.i.~i.::.~i~i.~:.i.i~i.:~.i.i.i.::.i.!.::.::.!.!.i.i.~::.::i!iiiiiiiiiiiiiii::i::ii.iiii::!::iii::i::iii!i!i::ii~ F o r C a s i n g Choices 3,500 psi Maximum anticipated surface pressure TVD surface shoe = 2,850 ft {(13.5'0.052)-0.11 }*TVDshoe =l 1,687 psiJ Estimated BH pressure at top of target zone Estimated Pressure= Top of Target, TVD = Overbalance, psi= Anticipated Mud Weight =[ 3,180.0 ppg 5,910 ft 150 psi 10.8 ppgJ Surface lead: Surface tail: Top West Sak, TM D = Design lead bottom 500 ft above the Top of West Sak = Annular area = Lead length * Annulus area = Excess factor = Cement volume required = Yield for Permafrost Cmt = Cement volume required =l TMD shoe (surface TD - 500' above West Sak) * (Annulus area) Length of cmt inside csg Internal csg volume Cmt required in casing Total cmt Excess factor Cement volume required Yield for Class G cmt Cement volume required 2,245 ft 1,745 ft 0.3132 cf/If 547 cf 15% 629 cf 2.17 290 sxI 2,850 ft 346 cf 80 ft 0.4340 cf/If 35 cf 381 cf 15% 438 cf 1.15 380 sxj OC'? 1 9 199;~ Alaska 0il & Gas Coils, uummissio~' Anchorage Casing Design / Cement Calculations 18-Oct-93 Production tail: TMD Top of Target, TMD Want TOO 500' above top of target Annulus area (9" Hole) (TD-TOC)*Annulus area Length of cmt wanted in csg Internal csg volume Cmt required in casing Total cmt Excess factor Cement volume required Yield for Class G cmt Cement volume required 6,94O ft 6,530 ft 6,030 ft 0.1745 159 cf 80 ft 0.2148 17 cf 176 cf 20% 211 cf 1.23 170 sxJ TENSION - Minimum Design Factors are: T(pb)=l.5 and T(js)=l.8 Surface (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =! 564OOO lb 2,850 ft 36.0O Ib/ft 102600.0 lb 16449.4 lb 86150.6 lb Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 639000 lb 2,850 ft 36.00 Ib/ft 102600.0 lb 16449.4 lb 86150.6 lb 7.41 Production (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =1 6O4O0O lb 6,94O ft 26.OO Ib/ft 180440.0 lb 29488.2 lb 150951.8 lb 4.01 Production (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 667000 lb 6,940 ft 26.00 Ib/ft 180440.0 lb 29488.2 lb 150951.8 lb OCT ! ..9 1995 Alaskrt 0il & 6as Cons. Oommissior' Anchorage Casing Design / Cement Calculations BURST - Minimum Design Factor = 1.1 Surface Casing: Burst = Maximum surface pressure Casing Rated For: Max Shut-in Pres = Design Factor =1 Production Csg: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For.- Inside pressure = Outside Pressure = Net Pressure = Design Factor =l COLLAPSE- Minimum Design Factor = 1.0 Surface Casing 1. Design Case - Lost circulation and Fluid level drops to 2000' TVD with 9.0 # Mud 2. Ext. Pres=Mud Wt*0.052*TVD-(2000'TVD of 9# Mud) Casing Rated For.' Mud Gradient = Ext. Pres. @ Bottom = Design Factor =l Production Csg 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 18-Oct-93 3520 psi 1687.2 psi 2.11 7240 psi 7004 psi 2878 psi 4126 psi 1.81 2020 psi 0.563 Ib/ft 670 psi 3.01 5410 psi 0.563 Ib/ft 3504 psi 1.51 (.)CT I ~)1993 · '-liaska 0il & Gas Oons. bul-~l~nissio~'~ Anchorage Casing Design / Cement Calculations 18-Oct-93 Surface Casing Choices OD ID Ib/ft Grade Metal X-Section Jt Strength Body Strength Collapse I 9.625 8.681 47 L-80 13.5724 sq. in. 1161000 lb 1086000 lb 4750 psi 2 9.625 8.835 40 L-80 11.4538 sq. in. 979000 lb 916000 lb 3090 psi 3 9.625 8.921 36 J-55 10.2545 sq. in. 639000 lb 564000 lb 2020 psi 4 10.750 9.950 45.5 J-55 13.0062 sq. in. 931000 lb 715000 lb 2090 psi Burst 6870 psi 5750 psi 3520 psi 3580 psi Production Casing Choices OD ID Ib/ft Grade Metal X-Section Jt Strength Body Strength Collapse Burst I 7.000 6.276 26 L-80 7.5491 sq. in. 667000 lb 604000 lb 5410 psi 7240 psi 0 CT 1 ~ t993 Alaska 0il & Gas Cons. (.;ommiss\O~'; Anchorage · .0" DIVERTER SCHEh, ATIC 5 5 ~ L .... J DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION , UPON INmAL INSTALLATION, CLOSE PREVENT]~ AND VERIFY THAT VALVE OPENS PROPERLY. ~ ~ PI=~-VEJ~PER IN THE EVENT THAT AN INFLUX OF W~LL,BORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM ,4,S A VARIANCE FROM 20AAC25.035(b) . 6. 20' - 2(X)0 PS! ~LAR PREVENTER SUP-ON WELD ST~ HEAD OlVERTER ~Y Wil'H ONE 2-1/16'- 2000 PSi BALL VALVE 10" HCR BALL VALVES WITH 10' DtVERTER UNES, A SINGLE VALVE OPENS AUTOMATICALLY UPON DIVERSION _a, iasks Oil & Anchor.'-~ge 3 2 13 5/8" 50(I~=SI BOP STACK 1. 16' - 2000 PSi STARTING HEAD 2. 11' - 3000 PS1 ~ HEAD 3. 11" - 3(X)0 PSi X 1~ - 5(XX) PS~ SPACER SR:X~ 4. 13..5/8' - 5(X)0 PSt PIPE P~ S. 13-5/~- 5000 P~ ~ ~ WI 7. 13-5,~' - 50GO PSI ,A~ ,Alaska Oil a c:,as c..o~s, ~' CHECK LIST FOR NEW WELL PERMITS ** Lease & Well ITEM (1) Fee (2) Loc APPROVE DATE ,[Ej thru 13] '~ [10 & 13] 'lit+ thru 22 (5) BOPE [23 thru 2 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4.' Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ 9. Does operator have a bond in force ................................... 10. Is a conservation order needed ....................................... 11. Is administrative approval needed .................................... 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27 28. YES NO Is lease nLrnber appropriate .......................................... Does well have a unique name & nLrnber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... (6) Other ~/~2'~ /~/~3 29. thr6'~l] 30. 31. [3 (8) Addl 33. geology' engineer inq' DWJ ~ MTM RAD]') ~ ~' ~.1- ~ rev 6/93 jo/6.011 FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone nLrnber of contact to supply weekly progress data ...... Additional requirements ............................................. // / INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA SHORE Additional remarks' UM ,X Exp~,X In j__ MERIDIAN' SM WELL TYPE' Redrill Rev 0 ZEZ ~0 u~--I