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Home My WebLink About193-175XHVZE 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. File Number of Well History File 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 n Other COMMENTS: Scanned by: iann~ Vincent Nathan Lowell Is/ [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ __THE MATERIAL UNDER THIS COVER HAS BEEN ON OR BEFORE P E MATE . W IA L UNDER THIS~ - .---------~_ ------_~ M AR K ER C:LORi~IFILM. DOC Memorandum State of Alaska Oil and Gas Conservation Commission Re: Cancelled or Expired Permit Action EXAMPLE: Point Mclntyre P2-36AXX AP1 # 029-22801-95 This memo will remain at the front of the subject well f'de. 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 ddll. Operators have asked us to adopt formal procedures for this class of permit application in order to prevent future database disparities. If a permit expires or is cancelled by an operator, the permit number of the subject permit will remain unchanged. The APl number and in some instances the well name reflect the number of preexisting reddils and or muitilaterais in a well. In order to prevent confusing a cancelled or expired permit with an active well or multilateral these case sensitive well identifiers will be changed for expired and cancelled applications for permits to 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 numbering methods described in AOGCC staff memorandum "Multi-lateral (wetibore segment) Ddlling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician Sep. 28. 1995 II'17ANi A~LASKA INC ARCO Alaska, ln~ Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 No. 3533 P. 2/2 Steve McMains Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject:. Cancellation of Approved Permits to Dffil for Unclrillecl Wells Dear Mr. McMains: Per our discussion last week, I am writing to request that you cancel several approved Permits to Drill for the Kuparuk River Unit. The wells were pern~tmd ~or different expansion and infill projects during the last two years. Due to information gained from other new wells or to changes in the drilling schedule, the wells I'd like to cancel were dropped from the program. While we will reuse the well names, by the time the wells are actually drilled the information will be significantly different than is on the current approved permits. Since this change requires re-submission of a Form 401 anyway, I think it would be easier on both of us to cancel the current permits. _ ' · I'd like to cancel the Permits to Drill for the following wells: ~3- I ~ ~ K~U ZE-04 q3- 1'~.5 I<~.U2E-lS KRU ZA-18 (Permit ~93-166, issue date 11/9/93) KRU ZA-22 (Permit ~33-163, issue date 10/27/93) KRU 3M-27 KRU 3H-24 KRU 3H-29 ' KRU 3H-30 oo q -oo3[ 9q-00,;21 2A-18 and 2A-22 inadvertently have two Permits to Drill, each; please cancel only the permit noted above. Thank you for calling our attention to this matter. If you have arty questions on the above wells please call me. DenisePetrash SEP 2 6 1995 ............ Drilling Engineer J. Hartz M. Zanghi $. Allsup-Drake (W1) Well File Alaska 0il & Gas Cons. COmmission AOGCC (Anchorage) Anchorage ATO-1286 ATO-1205 ATO-1205/ATO-370 (one copy f/each well listed above) AR38-$003-93 242-2503 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 January 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, Robert P Crandall Sr Petr Geologist encl jo/A:RPC:~drlstats .1/04/94 ALASKA WELLS BY ARCO PAGE I' OPERATOR pERMIT WELL NAME ARCO ALASKA INC 93-0166-0 KUPARUK RIV UNIT 2A-18 ARCO ALASKA INC 93-0152~0 KUPARUK RIV U~IT 2A-19 ARCO ALASKA INC 93-0151-0 KUPARUK RIV UI~IT 2A-20 ARCO ALASKA INC 93-01~3-0 KUPARUK RIV UNIT 2A-22 ARCO ALASKA INC 93-0144-0 KUPARUK RIV UNIT 2A-24 ARCO ALAS~.A INC 93-0188-0 KUPARUK RIV I/NIT 2E-04 ARCO ALASKA INC 93-0179-0 KUPARU~ RIV UNIT 2E-05 ARCO ALASKA INC 93-0169-0 KUPARUK RIV UNIT 2E-06 ARCO ALASKA INC 93-0104-0 KUPARUK RIV UNIT 2E-07 ARCO ALASKA INC 93-0189-0 KUPARUK RIV U~IT 2E-08 ARCO ALASKA INC 93-0174-0 KUPARUK RIV UI~IT 2E-17 ARCO ALASKA INC 93-0175-0 KUPARUK RIV UI~IT 2E-18 ARCO ALASKA INC 93-0187-0 KUPARUK RIV U~IT 3M-23 ARCO ALAS~(A INC 93-0195-0 KUPARUK RIV U~IT 3M-24 ARCO ALASKA INC 93-0196-0 KUPARUK RIV UNIT 3M-25 AR~O ALASKA INC 93-0193-0 KUPARUK RiV UNIT 3M-26 ARCO ALASKA INC 92-0040-0 KUPARUK RIV UNIT 3R-16 ALASKA OIL AND GAS CONSERVATION COMMISSION November 15, 1993 A. W. McBride Area Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 WALTER J. HIGKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Re: Kuparuk River Unit 2E-18 ARCO alaska, Inc.' Permit No: 93-175 Sur. Loc. 667'FSL, 160'FWL, Sec. 36, TllN, R9E, UM Btmhole Loc. 1952'FNL, 1052'FEL, Sec. 1, T10N, R9E, 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. Chairman~ BY ORDER OF THE COMMISSION dlf/Enclosures cc.' Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. printed on recycled paper b y ~oD. ALAS,, ~' OIL AND GAS CONSERVATION COMMIS PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill [] lb Type of Well Exploratory [] Stratigraphic Test [] Development Oil X Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone X Multiple Zone 2.. Name of Operator 5. Datum Elevation (DF or KB) 1 0. Field and Pool ARCO Alaska, Inc. RKB 146', Pad 105' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25665, ALK 2586 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 2O AAC 25.025) 667' FSL, 160' FWL, SEC. 36, T11N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1800' FNL, 1288' FEL, Sec. 1, T10N, R9E, UM 2E-18 #U-630610 At total depth 9. Approximate spud date Amount 1952' FNL, 1052' FEL, Sec. 1, T10N, R9E, UM 1/1 0/94 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2E-07 8362' MD 1052' ~ TD feet 12.5' ~ 900' MD feet 2560 6351' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 1 000 feet Maximum hole angle 47.79° Maximum surface 2043 psig At total depth (TVD) 3041 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement , Hole Casing Weight Grade Coupling ,Length MD TVD MD TVD linclude stage dataI 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' _+200 CF 12.25" 9.625" 36.0# Jo55 BTC 4094' 41' 41' 4135' 3451' 420 Sx Arcticset III & , HF-ERW 540 Sx Class G 8.5" 7" 26.0# L-80 BTCMOE 8321' 41' 41' 8362' 6351' 170Sx ClassG 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 depth True Vertical depth (~t°rnU(~tuUcrta°lr J~ E C E IV E D Surface Intermediate Production N 0V - 9 199 Liner Perforation depth: measured Alaska 0ii & Gas Cons. Commission true vertical Anchorage 20. Attachments Filing fee X Property plat [] 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 foregoing is true and correct to the best of my knowledge Signed /~J~~ Title Area Drillin~l En~lineer Date ~ -- Commission Use Only Number I APl number I Approval..Oate . ,~,. /~,-~ I See cover letter for Permit. ,..~ _,/~' ~" 5 0- 0 ~ ~ -' ~ .~ ~--~. ~:~ ///-/.~ '~ other rec{uirements Conditions of approval Samples required D Yes [] No Mud Icg required r"] Yes .J~ No Hydrogen sulfldemeasures r"l Yes ,~ No Directional survey required ~ Yes r"] No Required working pressure for BOPE r"] 2M ~ 3M r'"] 5M [] 1OM [] 15M Other: Original Signed By David W. Johnston byorder of Approved by Commissioner the commission Date {'/' ~""~ Form 10-401 Rev. 7-24-89 Submit in triolicate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 2E-18 , . . . . . . . 10. 11. 12. 13. 14. 15. 16. 17. 18. Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (4135')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 (8362') 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 and full opening valve for running cased hole logs. Secure well and release rig. Run cased hole cement evaluation. ND full opeing 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. DRILLING FLUID PROGRAM Well 2E-18 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.8 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 11.3 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 2043 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 2E-18-is 2E-07. As designed, the minimum distance between the two wells would be 12.0' @ 880' 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. RECEIVED N 0V - 9 t99,~ A~aska 0il & Gas Cons. Anchorage Casing Design / Cement Calculations 9-Nov-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 2E - 18 4,135 ft 3,451 ft 8,362 ft 6,351 ft 3,019 ft 7,925 ft 6,016 ft 3400 psi t~~._~i~!i~i=~** See Page 4 ::::..-,~:¥:~<.:..:~.~.,.-.~..>.:,<;. ,.~....~.~+~....~......~,~...,~..~..~<..~.,.../~ · ..~, <... ×. For Casing Choices 3,500 ps~ Maximum anticipated surface pressure TVD surface shoe = 3,451 ff {(13.5'0.052)-0.11 }*TVDshoe =[ 2,043 psiJ Estimated BH pressure at top of target zone Estimated Pressure= Top of Target, TVD = Overbalance, psi= Anticipated Mud Weight =1 3,400.0 ppg 6,016 ft 150 psi 11.3 ppgJ Surface lead: Top West Sak, TMD = 3,019 ft Design lead bottom 500 ft above the Top of West Sak = 2,519 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 789 cf Excess factor = 15% Cement volume required = 907 cf Yield for Permafrost Cmt = 2.17 Cement volume required =[ 420 sxI Surface tail: TMD shoe = 4,135 ft (surface TD - 500' above West Sak) * (Annulus area) = 506 cf Length of cmt inside csg = 80 ft Internal csg volume = 0.4340 cf/If Cmt required in casing = 35 cf Total cmt = 541 cf Excess factor = 15% Cement volume required = 622 cf Yield for Class G cmt = 1.15 Cement volume required =[ 540 sxJ RECEIVED NOV - 9 1993 Alaska Oil & Gas Cons. OommisstO~ Anchorage Casing Design/Cement Calculations 9-Nov-93 Production tail: TMD = 8,362 ft Top of Target, TMD = 7,925 ft Want TOC 500' above top of target = 7,425 ft Annulus area (9" Hole) = 0.1745 (TD-TOC)*Annulus area = 164 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.2148 Cmt required in casing = 17 cf Total cmt = 181 cf Excess factor = 15% Cement volume required = 208 cf Yield for Class G cmt = 1.23 Cement volume required =1 170 sx TENSION - Minimum Design Factors are: T(pb)=l.5 and T(js)=l.8 Surface (Pipe Body): Casing Rated For: Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air - Length * (WEft) Buoyancy - Weight of displaced mud Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =[ 564000 lb 4,135 ft 36.00 Ib/ft 148860.0 lb 24994.5 lb 123865.5 lb 4.61 Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) 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 4,135 ft 36.00 Ib/ft 148860.0 lb 24994.5 lb 123865.5 lb Production (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =1 604000 lb 8,362 ft 26.00 Ib/ft 217412.0 lb 37210.2 lb 180201.8 lb 3.41 Production (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Casing Wt (Ib/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = ._ Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 RECEIVED NOV - 9 199;5 0ii & Gas Cons. o0mmiss~O~'~ 667000 lb 8,362 ft 26.00 Ib/ft 217412.0 lb 37210.2 lb 180201.8 lb 3.71 Casing Design/Cement Calculations BURST- Minimum Desicjn 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 Desi(jn 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 =1 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 9-Nov-93 3520 psi 2043.0 psi 1.71 7240 psi 7248 psi 2939 psi 4308 psi 1.71 2020 psi 0.590 Ib/ft 1100 psi 1.81 5410 psi O.59O Ib/ft 3748 psi 1.41 RECEIVED NoV -- 9 Alaska 0ii & Gas Cons. C0nt~tss't0~ Anch0rag~ Casing Design / Cement Calculations 9-Nov-93 Surface Casing Choices OD ID Ib/ft Grade Metal X-Section Jt Strength Body Strength Collapse Burst I 9.625 8.681 47 L-80 13.5724 sq. in. 1161000 lb 1086000 lb 4750 psi 6870 psi 2 9.625 8.835 40 L-80 11.4538 sq. in. 979000 lb 916000 lb 3090 psi 5750 psi 3 9.625 8.921 36 J-55 10.2545 sq. in. 639000 lb 564000 lb 2020 psi 3520 psi 4 10.750 9.950 45.5 J-55 13.0062 sq. in. 931000 lb 715000 lb 2090 psi 3580 psi Production Casing Choices OD ID Ib/ft Grade Metal X-Section Jt Strength Body Strength Collapse I 7.000 6.276 26 L-80 7.5491 sq. in. 667000 lb 604000 lb 5410 psi 2 7.000 6.276 26 J-55 7.5491 sq. in. 490000 lb 415000 lb 4320 psi Burst 7240 psi 4980 psi RECEIVED N OV - 9 199;) Alaska 0il .& Gas Cons. C0mmiSSi0~ ;Anchorage 0 250 _ 500_ 750. 1000. _ 1250 _ _ 1500_ _ 1750_ _ 2000_ - 22.50 _ 2,5O0 2750 - - - ,5500 _ - ,5750_ _ 4000_ - 4250_ 4500_ _ 5750_ 5500_ _ 5750_ _ $250 _ 65OO /. RKB ELEVATION: 146' iARCO ALASKA, ][TIC Structure : Pad 2E Well : 18 I Field : Kuparuk River Unit Location : North Slope, Alaska! Created by : jones For: MATllEWS / ELLIS Date p{otted : 20-Aug-93 Plot Reference is 18 Version #3, Coordinates are in feet reference slot #18. S 57.23 DECx E True Vertical Depths ore reference wellhead. 4557' (TO TARGET) Baker Hughes NTEQ--- , o.oo E a st - - > ,500 0 300 600 900 1200 1500 1800 2100 2400 2700 3DO0 ,33003600 ,t9004200 I I [ t I I I I I I I i [ I I [ t I ] I I t i I I I [ I I ! I 300 KOP TVD=IO00 TMD=IO00 DEP=O ~.. [667' FSL, 160' FWL I ~ ISEC. 36,.Tlm, RgE I 50o 6.00 BUILD 3 DEC / 100' ~ - ~ 1 2.00 B/ PERMAFROST ~ _ 600 · 1~ 15.00 TVD=1501 TMD=1507 DEP=67 ~ - 27.00 _~2oo ~ . '~3.00 T/ UGNU SNDS - 3. ~, 45.00 ~ _,,,oo I ~ T/ W SAK SNDS ~ _2100 ~ ' TVD--3251 TMD=5838 DEP=1549 ~ i TARGET ' ~ TVD=6016 3000 ~ 9 5/8" CSG PT TVD=3451 TMD=4136 DEP=1769 ~)1~pD_-=47~52~ ~ SOUTH 2467 EAST 3832 K-lO 1VD=3781TMD=4627 DEP=2133 "~ · ~ I SEC. 1, TIO", RgE I MAXIMUM ANGLE RECEIVED K-5 TVD=5Ogl TMD=6576 DEP 3577 NOV - 9 199;5 BEGIN ANGLE DROP TVD-5736 TMD-7536 DEP=4288 ~laskaOil &Anch0rageGasConsC0~tSs[Otl 46.00 DROP 2 DEO / 100' 42.00 TARGET -T/ ZONE C(ROD) TVD=6016 TMD=7925 DEP=4557 TARGET ANGLE T/ ZONE A WD=6092 TMD=8024 0EP=4621 ~ 40 DEG B/ KUP SNDS WD=6198 TMD=B165 DEP=4710' TD / ?" C~C PT 3'I/])=6951 TMD=8360 .......... '5 ........... '5 ..... ;~0' ;5 ....... ;~0' ' 0 250 500750 1000 12 0 1500 1750 2000 2250 2500 27 0 3000 ,3250 3 3 0 4000 4250 4500 4 5000 Scale 1 : 125.00 Vertical Section on 122.77 azimuth with reference 0.00 N, 0.00 E from slot #18 ARCO ALASKA, Structure : Pad 2E Field : Kuparuk River Unif Well : 8/ 18 / 7 / 17 / 6 Location · Norfh Slope, Aloska~ Scole I · 50.00 50 1 O0 15O I I I I I 800 100{ 1 East 200 250 500 I I I I I --> 550 400 450 500 550 I I I I I I I I I 1200 1400 16OO 1400 1600~- 1400 1600 1800 1800 2000 1800 1800 2000 2000 2000 18; 750 _700 _650 _600 _550 _500 _450 _400 _350 _500 _250 RECEIX/£D ,~KUPARUK RIVER U~.T~ 20" DIVERTER SCHEMATIC 6 5 ! 4 3 DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION . . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUC'FOR 2. SUP-ON WELD STARTING HEAD 3. DIVEFITER ASSEMBLY WITH ONE 2-1/16'- 2000 PSI BALL VALVE 4. 20" -2000 PSI DRILUNG SPOOLWlTH TWO 10' OU'I1.EI~. 5. 10' HCR BALL VALVES WITH 10' DIVEFrrER MNES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20' - 2000 PSI ANNULAR PREVENTER RECEIVED NOV - 9 199~ ^laska OJJ & Gas Cons. Commission An~hor~e ,,I 7 6 5 4 I3 2 1 13 518" 500( SI BOP STACK 1. CHECK AND FILL ~ULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ~ULATOR PRESSURE IS 3000 PSI WITH 3. OBSERVE TIME, THEN I:AJ35E ALL UNITS 81MULTANEOUSLY AND IS 45 SECONDS CLO~ING TIME AND 1200 I~1 REMAINING PRESSURE. 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOL.D4X)WN ~FIEW~ ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT ~ PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-~ SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. AU. OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE UNE VALVE~ 6~ CLOSE TOP PiPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3(XX) PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, UNES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING PosmvE SEAL CHOKE. & OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BoI'rOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PiPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BUND RAMS AND TESTTO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING PoSmON. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. ~EST KELLY COCKS AND INSIDE BOP TO 3000 PSI WfTH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILUNG SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DNLY. 1. 16' - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13.5/8"- ~ P~ PIPE RAMS 5. 13-5~- 5000 PSI DF"..G SPOOL W/ CHOKE AND KILL UNES 6. 13,,5/8'- ~ ~ ~~ ~ W/ PiPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8' - 5000 PSI ANNULAR RECEIVED N OV - 9 Alaska Oil & Gas Cons. OommissiO~ Anchorage ITEM (1) Fee (2) Loc CHECK LIST FOR NEW WELL PERMITS ** z~L~APPROVE ,Pc__ '['2 thru 8 15]" [10 & 13] ' - (4) Casg [14 thru 22~ (5) BOPE [25 thru . 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Company //~.. o Lease & Wel 1 YES Is permit fee attached ............................................... Is well to be located in a defined pool .............................. Is well located proper distance from property line ................... ~ . Is well located proper distance from other wells ..................... Is sufficient undedicated acreage available in this pool ............. Is well to be deviated & is wellbore plat included ................... '_~_~. ... Is operator the only affected party .................................. ~__ . Can permit be approved before 15-day wait ............................ Does operator have a bond in force ................................... ~.. Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease ngrnber appropriate ................... ' ...................... L Does well have a unique name & ngrnber ................................ ~ ... 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 well bore 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 ~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas,probable ...................................... '' ) REMARKS (6) Other ~:~c- ~//~//~_~ 29. [29 thr~ ~i~ 30. 31. (7) Contact "~-[3 '2f//~//~'~ 32. (8) Addl 33. geology: engineer ing: -' -- TAB ~ u//~./9,~, /' ~" 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 ncrnber of contact to supply weekly progress data ...... Add i t i onal requ i rements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE ?~'/oo ~ I-o,'1 F~o //"go o, ,O Additional remarks' UM ?~ MERIDIAN' SM WELL TYPE' Exp~'~ In j,, Red r i 11 Rev 0 -.~ -rz ~0 m z