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Home My WebLink About193-166XHVZE 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. /~3"//~ ~ 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 · [3 Logs 'of various kinds . [] Other COMMENTS: Scanned by: Diann~ Vincent Nathan Lowell n TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 0 3 2 0 01 PL W M ATE IA L U N D E~ TH IS M ARK ER Memorandum State of Alaska Oil and Gas Conservation Commission Cancelled or Expired Permit Action EXAMPLE: Point Mclntyre P2-36AXX AP1 # 029-22801-95 This memo will remain at the from of the subject well ~e. Our adopted conventions for assigning APl numbers, permit numbers and well names did not specifically address expired or cancelled permits. This omission has caused some inconsistencies 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 reddlls 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 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) Drilling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician ,.4 Sep. 26. 1995 i1' 17AM A[~0.~LASKA INC ARCO Alaska, Inc. ~, ~,,t ,' Post Office Box 100360 Anchorage. Alaska 99510q0360 Telephone 907 276 1215 3533 P. 2/2 Steve McMains Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject:. Cancellation of Approved Permits to Drill/or Undrilled Wells · Dear Mr. MdVfains: " Per our discussion last week, I am writing to request ~at you cancel several approved Permits to Drill [or the Kupamk River Unit. The wells were permitted for · different expansion and infill projects during the last two years. Due to info~fion . . · gained from other new wells or to changes in the drilling schedule, the wells I'd like · ~' to cancel were dropped [rom 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 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 [ollowing wells: Ig8 muzs-oi q3-- K U2EqS KRU 2A-18 IP~t ~3-166, issue date 11/~/~3) KRU 2A-22 (Pem~t #93-163, issue date 10/27/93) KRU 3M-27 I~U 3H-24 KRU 3H-29 · KRU 3I-I-30 OOO Oo31 qq-O0;21 2A-18 and ZA-Z2 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. Sincerely, ' ' ' - .-.,, c: F~ · ' DenisePetrash SEP 26 1995 Drilling Engineer M. $. Allsup-Drake (W1) Wen File Alaska 0ii & Gas Cons. COmmission AOGCC (Anchorage) Anchorage ATO-1286 ATO-1205 ATO-1205/ATO-370 (one copy f/each well listed above) AFI38-$003-93 2¢2-2603 ALASKA OIL AND GAS CONSERVATION COMMISSION PETROLEUM WELL RECORD 09/18/95 WELL WELL I LEASE NUMBER I SRT I~MBER .ii I CONFID CODE 41327 GEOLOGIC ON-OFF CODE ] AREA SHORE 890 ARCTIC SLOPE ON ~DPOL FIELD AND POOL CODE I NAME MULTIiCOMP NUMB FLD&POOL FLD&POOL COMP 000000 000000 I UNIT UNIT CODE ] NAME 11160 KUPARUK RIVER ELEVATIONS BOTTQM HOLE LQCATION FEET/DIR/FEET/DIR/SEO/TWPI R~G I MER PERMIT APPROVED :1/o9/93 FOQTAGE DRILLED FEET FI~TAL c , ss/s? ?usl CLASS I STATUS PERM [SSSV THICK DEPTH REQUIREMENTS NO NO YES PERMIT ISSUED FRM TST SALEST ACCTG/ DATE SPUDDED DATE COMP, ETC STATUS RECORD DATE LAST UPD 11/09/93 04/07/95 ALASKA OIL AND GAS CONSERVATION CO~I~IIS$1ON ~WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, AI.A~KA 99501-3192 PHONE: (907) 279.1433 TELECOPY: (907) 276-7~42 January 10, 1994 Phyllis Billingsley ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Dear Ms Billingsley: The CommissiDn 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 ! 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 OPERATOR ARCO ALASKA ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA iNC ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA INC ARCO ALAS~ 'INC ARCO ALASKA INC A/~CO ALASKA =NC A~CO ALAS~(A INC ARCO ALASKA INC A~CO A3~ASKA INC ARCO ALASKA AR~O ALASKA INC ALASKA WELLS BY ARCO PERMIT 93-0166-0 93-0132-0 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 93-0173-0 93-0187-0 93-0193-0 93-0196-0 93-0193-0 92-0040-0 WELL NAME KUPARUK RIV UNIT KUPARUK RIVUNIT KUPARUK RIVUNIT KUPARUK RIV Ul~IT KUPARUK RIVU~IT KUPARUK RIVUNIT KUPARUK RIVUNIT KUPARUK RIVLT~IT KUPARUK RIV UNIT KUPA~UK RIVUNIT KUPARUK RIVUNIT KUPARUK RIVUNIT KUPARUK RIVUNIT K~JPARUK RIVUNIT KUPA~UK RIV %;NIT KUPARUK RIV UNIT KUPAi~U~ RIV%T~IT 2A-18 2A-19 2A-20 2A-22 2A-24 2E-04 2E- 03 2E-06 2E- 07 2E- 08 2E-1T 2E-18 3M-23 3M-24 3M-26 3R-16 · PAGE Memorandum To: Em: Subj: File KRU 2A-18 Surface Pressure Estimate and BOP Test Pressure State of Alaska Oil and Gas Conservation Commi.~ion ARCO estimates a BHP of 3710 psig at 2A-18 on the APD, which is higher than "normal" for Kuparuk development wells. Using 3710 psig (.585 psi/fi) yields a WHP of 3296 psig assuming a full column of gas to surface. This would mean BOPE would need to be tested to 5000 psi. ARCO's method to determine maximum surface pressure uses a calculation of fracture pressure at the surface casing shoe to estimate the WHP. By their estimate, the formation breaks down before a surface pressure of 1687 psi is reached. This results in a BOP test pressure of 3000 psi. I called Wayne McBride at ARCO to discuss the higher BHP. Mr. McBride said the waterflood in the 2A Pad area has caused elevation of reservoir pressure to the estimated levels. He stated that ARCO would have to set pipe above the Kupamk sands whereas the usually drill thru them and then set pipe. In addition to a higher setting depth on the casing, he said ARCO would have to upgrade the 3000 psi casing head if the AOGCC requires a higher pressure level for BOP tests. ARCO is moving the rig to 2E pad and don't plan to return to 2A pad until next year. They apparently are going to try to reduce reservoir pressure in the 2A area before continuing drilling. I suggested they contact the Commission prior to proceeding at 2A pad so that a solution can be achieved to ensure well design and BOP test requirements are compatible. ALASKA OIL AND GAS CONSERVATION COM~IISSION November 9, 1993 A W McBride Area Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, AI.ASKA 99501.3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Re .' Kuparuk River Unit 2A-18 ARCO Alaska, Inc. Permit No: 93-166 Sur. Loc. 736'FSL, 227'FWL, Sec. 14, TllN, RSE, UM Btmhole Loc. 184'FNL, 663'FWL, Sec. 24, TllN, RSE, 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 BOP~ 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. · Chairm~ BY ORDER OF THE COMMISSION dlf/Enclosures Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ p, in~ed on ,ecycled paper b y C, D ' i~ STATE OF ~ ~ ALA;SKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill r-] lb Type oI' Well Exploratory r"l Stratlgraphlc r'l Development Oil X Teat Re-Entry r"! Deepen D Service r'~ Development Gas r'l single Zone X Multiple Zone r'! 2.. Name o! Operator ' 5. Datum Elevation (DF or KB) 10. Field and Peel 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, Anchora~le, AK 99510-0360 ADL 25570, ALK 2668 4. Location of Well at surlace " '' ' 7. Unit or property Name 11. Type Bond (~ee 20 AAC 736' FSL, 227' FWL, SEC,:~i.4; T11N, R8E, UM Kuparuk River Unit Statewide At top of productive interval (;O TARGET ) 8. Well number Number 65' FNL, 607' FWL, Sec. 24, T11N, R8E, UM 2A-18 #U-630610 At total depth 9. 'Approximate spud date Amount 184' FNL, 663' FWLr Sec. 24~ T11Nr R8E~ UM I 1/04/93 $200~000 12. Distance lo nearest 13. Distance lo nearest well 14. Number of acres in property 15. Propceed depth (MD and TVD) property line 2A- 01 6520' MD 1977' @ TD feet 12.8' @ 1680' MD feet 2560 6347' TVD feet 16. To be completed for deviated wells ' 17. Anticipated pressure (see 20 AAC 26.035'(e)(2)) Kickoff depth 3212 feel Maximum hole angle 20° · Maximum su~fa~e 1.6,87 paig At total depth (TVD) 3710 18. Casing program Settin;l Depth' size Specifications Top, Bottom Quant~ of cement Hole Casing Weight Grade Couplin~l Length MD TVD MD TVD llnclude stave dataI 24' 16' 62.5# H-40 Weld 80' 41' 41' 121' 121' +zOO CF i 12.25' 9,625' 36.0# J-55 BTC 2809' 41' 41' 2850' 2850" 290 Sx Arcticset III & HF-ERW 380 Sx Class G i I 8.5' 7' 26.0# L-80 BTCMOC 6479' 41' 41' 6520' 6347' 160 Sx Class G HF-ERW Top 500' above Kuparuk 19. To be complete( for Redrlll, Re,entry, and Deepen Operations. Present well condition summary Total depth: measured f e e t Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing ConductorStructural Length Size Cemented R E (~ Ee~~:~h True Vertical depth Surface Intermediate P,o uc,,on 0 CT 2 2 199; Liner Perforation depth: measured Alaska 0il & Gas Cons. C0m[nissi0n true vertical Anchorage 20. Attachments Filing lee X Property plat r"! BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time Vs depth plot D Refraction analysis D Seabed report ri 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~-~~ Title Area Dr!lling Engineer Date ,~ 0/~'/ " Commission, Use Only · / Permit~ ~Number*' ~/~',~'I, APl50. /<:3number'~ -. -~. ,<~/~ ~ I Approval date//.... ~-~...._~.~ I See cover letter Ior other requirements Conditions of approval Samples required r'l yes I~ No Mud Icg required r-I Yea ~] No Hydrogen sulfide D Yes I~ No Directional survey required l~ Yes D No measures Required working pressure for BOPE D 2M r"! 3M II~ 5M D 10M D 15M Other:. Original Signed By by order of Approved by David W. Johnston Commissioner the commission .Date ~/ ~//'~ "'2'2 m 10-401 cate I . . . . Se . . . . 10. 11. 12. 13. 14. 15. 16. 17. 18. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 2A-18 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 (6520') 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. RECEIVED OCT 2 2 1995 Alaska Oil & Gas Cons. C0rnm~sS~0n Anchorage DRILLING FLUID PROGRAM Well 2A-18 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8' surface casi ,ng 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% Weight up to TD 11.3- 11.7 10-18 8-12 35-50 2-4 4-8 4-5 thru Kuparuk 9.5-10 <12% Drillino Fluid Svstern; T~.ndem B~:andt 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: "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 2^-18 is 2A-01. As designed, the minimum distance between the two wells would be 12.8' @ 1680' 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 0CT 2 2 199 Alas .ka 0il & Gas Cons. C0mmtsst0t~ 'Anch0m~le Y 250 _ 500 _ _ 750 _ - 1000_ 1250_ 1500_ _ 1750_ _ 2000_ _ 2250_ _ 2500_ _ 2750_ · _ 3000_ _ 3250_ _ 3500_ _ 3750_ _ 4000_ _ 4250_ _ 4500 _ _ 4750 _ _ §000 _ _ 5250_ _ 60001 6250t 65001 RKB ELEVATION: 135' Ai?:CO ALASKA, Inc. Structure : Pad 2A Well : 18 Field : Kuparuk River Unit Location : North Slope, Alaska S 25.38 DEG E 88'7' (TO TARGET) Created by jones For: M ELLIS Date plotted : 29-Sep-95 Plot Reference is 18 Version #2, Coordinates are in feet reference slot #18. True Vertical Depths are reference wellhead. Baker Hughes INTEQ --- B/ PERMAFROST TVD=1490 T/ UGNU SNDS TVD=1635 T/ W SAK SNDS TVD=2235 B/ W SAK SNDS TVD=2735 KK;1pO ~-I~Dd21"~2 ] M~y: 2~21: 6.00 BUILD 3 BEG / 100' 1 2.00 18.00 EOC TVD=3865 TMD=3879 OEP=115 s ...... ,0.00 East lO0 0 lO0 200 300 I I I I I I I I I SURFACE LOCATION: 736' FSL, 227' FWL SEC. 14, T11N, RBE TARGET LOCATION: 65' FNL, 607' FWL SEC. 24, T11N. RBE TARGET 1VD=5985 TMD=6134 DEP=~7 SOUTH 801 EAST 380 --> 400 5O0 600 I I I I I I 700 100 0 100 200 3O0 4OO 500 600 700 80O . gO0 1000 1100 0 I I V K-5 TVD=4455 TMD=4506 DEP=330 ITD LOCATION: 184' FNL, 663' FWL SEC. 24, Tl lN, RBE AVERAGE ANGLE 20 DEG TARGET TVD=5985 TMD=6134 DEP=887 KUP SNDS WD=6159 TMD=5320 DEP=950 TD / 7" CSG PT TVD=6347 TMD=6520 DEP=I018 I I I I I I I I / I I 0 250 500 750 1000 ! 250 s.~ 1:1~ RECEIVED OCT 2 2 1995 Alaska Oil & Gas Cons. Commission Anchorage Scale 1 : 50.00 50 1 O0 150 I I I I I ARCO ALASKA, Inc. Strudum: Pad 2A Well: 18/ 22 rldd: Kuparuk River Unit Looaflon: Norlh S~ope, Ak~ka East 200 I I 3000 250 4000 3800 3600 1800 600 3600 000 300 350 I I I 40O 1400 2400 .00 3800 4000 4200 45O 1100 _ 1050 _ 600 _ 550 _ 500 _ 1000 EIVED OCT 2 2 199~ Oil& Gas Cons. Comm'tssio~ Anchoraa. e _ 950 _ 900 _ 850 A - I _ 800 I _ 750 Z 0 - -~ I _ 700 ~ _ 65O _ 450 Casing Design ! Cement Calculations 21-0ct-93 Well Number: 2A-18 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 2,850 ft 2,850 ft 6,520 ft 6,347 ft 2,235 ft 6,134 ft 5,985 ft 3500 psi ~"i:i~-~:.::~:!~.:;~' ~::~i.~ ~ ::~" ...... ~:; "~.".":-<; ** · .:'"':i:~':;':~:;:i:~;':~;':-~;~'""';:~.::.':~-~.~:~. .,..~.~:~; ~&~.~_.P~..;._~ ;~;-'~i:~.?,'-~ .~i'~-~ - :'-., · · E.: :~.~:~..:l~JlJl~JlJ~i For Cas~n Chmoe 3,500 psi Maximum anticipated surface pressure 'I'VD surface shoe = 2,850 ft {(13.5'0.052)-0.11 }*TVDshoe =1 1,687 psiI Estimated BH pressure at top of target zone Estimated Pressure= Top of Target, TVD = Overbalance, psi= Anticipated Mud Weight =1 3,500.0 ppg 5,985 ft 150 psi 11.7 PPgl Surface lead: Top West Sak, TMD = 2,235 ft Design lead bottom 500 ft above the Top of West Sak = 1,735 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 543 cf Excess factor = 15% Cement volume required = 625 cf Yield for Permafrost Cmt = 2.17 Cement volume required =1 290 sxI Surface tail: TMD shoe = 2,850 ft (surface TD - 500' above West Sak) * (Annulus area) -- 349 cf Length of cmt Inside csg = 80 ft Internal csg volume = 0.4340 cf/If Cmt required in casing = 35 cf Total cmt = 384 cf Excess factor -- 15% Cement volume required = 442 cf Yield for Class G cmt = 1.15 Cement volume required =1 380 sxJ REEEIVED 0 CT 2 2 199; Alaska Oil & Gas Cons. Commission Anchorage Casing Design ! Cement Calculations 21-Oct-93 Production tail: TMD = 6,520 ft Top of Target, TMD = 6,134 ft Want TOC 500' above top of target = 5,634 ft Annulus area (9" Hole) = 0.1745 (TD-TOC)*Annulus area = 155 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.2148 Cmt required in casing = 17 cf Total cmt = 172 cf Excess factor = 15% Cement volume required = 198 cf Yield for Class G cmt = 1,23 Cement volume required =1 16°,s,xl TENSION - Minimum DeSion Factors are: T(DbI=I.5 and T¢is}=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 2,850 ft 36.00 Ib/ft 102600.0 lb 17804.2 lb 84795.8 lb 6.7J 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 (lb/fi) -- Dead Wt in Air -- Buoyancy = Tension (Joint Strength) = Design Factor =1 639000 lb 2,850 ft 36.00 Ib/ft 102600.0 lb 17804.2 lb 84795.8 lb Production (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Production (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud RECEIVED oc-r 2 2 1995 Naska 0il .& Gas Cons. Comm'~t°~ Anchorage Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy -- Tension (Pipe Body) = Design Factor =1 Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy -- Tension (Joint Strength) = Design Factor =1 604000 lb 6,520 ft 26.00 Ib/ft 169520.0 lb 29985.3 lb 139534.7 lb 4.31 667000 lb 6,520 ft 26.00 Ib/ft 169520.0 lb 29985.3 lb 139534.7 lb 4.81 Casing Design ! Cement Calculations BURST - Minimurrt De;ign Factor = 1.1 Surface Casing: Burst = Maximum surface pressure Casing Rated For: Max Shut-in Pres = Design Factor =! 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 =1 COLLAPSE- Minimum Desigrt Fa,gtor = 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 =[ 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. O Bottom = Design Factor =1 21-Oct-93 3520 psi 1687.2 psi 2.1] 7240 psi 7371 psi 2937 psi 4433 psi 1.61 2020 psi 0.610 Ib/ft 8,,02 psi 5410 psi 0.610 Ib/ft 3871 psi 1.41 RECEIVED OCT 2 2 199 Alaska 0il & Gas Cons. Comtatss[o~ Anchorage Casing Design ! Cement Calculations 21-0ct-93 OD E) Iblft I 9.625 8.681 47 2 9.625 8.835 40 3 9.625 8.921 36 4 10.750 9.950 45.5 Surface Casing Choices Grade Metal X-Section Jt Strength L-80 13.5724 sq. in. 1161000 lb L-80 11.4538 sq. in. 979000 lb J-55 10.2545 sq. in. 639000 lb J-55 13.0062 sq. in. 931000 lb BodyStrength 1086000 lb 916000 lb 564000 tb 715000 lb Collapse 4750 psi 3090 psi 2020 psi 2090 psi Buret 6870 psi 5750 psi 3520 psi 3580 psi OD E) 1 7.000 6.276 Production Casing Choices I bift Grade Metal X-Section Jt Strength Body Strength Collapse 26 L-80 7.5491 sq. in. 667000 lb 604000 lb 5410 psi Burst 7240 psi RECEIVED OCT 2 2 199;~ Alaska Oil & Gas Cons. Commission Anchorage PARUK RIVER UNIT 20" DIVERTER SCHEMATIC I 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" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE 4. 20" - 2000 PSI DRILLING SPOOLWITH TWO 10" OUTLETS. 5. RECEIVED 0 CT 2 2 199~ Alaska 0il & Gas Cons. Commission Anchorage . 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 20" - 2000 PSI ANNULAR PREVENTER EDF 3/10/92 r-I ,6 , 5 I I3 13 5/'8" 5000 i BOP STACK 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 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 TE~T 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 AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN, 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR 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 LOW 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 Bo'FrOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 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. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR, 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 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" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR RECEIVED 0CT 2 2 1995 Alaska 0il & Gas Cons. commisstOr~ Anchorage .... CMECK LIST FOR NEW WELL PERMITS .... ITEM APPROVE DATE [2 ~hru 8] (4) Casg ~ 1'//~ [:14 thru 22]' ' [23 thru 28]' ~ . 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. (5) BOPE 9. · [29 thr6 3:~] 30. 31. (7) Contact~~[ 3 ~~.~ 32. (8) Addl 33. geology: engineering.'__ DW~ ~. RAD]) rev 6/93 jo/6.011 Company Is permit fee attached - · · $ · · ..,~. · ..... ® . m... ® .. · .. · .. · ........,~ t,.. m.,i, · Is well to be located in a deflned pool .............................. Is wel 1 located proper distance from property 1 ine ................... 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 ................... I operator the l y affected party s on ,,,.,,.,,,,,,,,,,,.,,,,,,,,,,, ,,, 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 number appropriate .......................................... ~ Does well ~have a unique name 8 nt~nber ................................ Is conductor string provided ......................................... Wi 1 1 surface casing protect al 1 zones reasonably expected to serve as an underground source of drinking water .................. ~h~ Is enough cement used to circulate on conductor & surface ............ ~ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horlzons ..................... ~!~ Will all casing glve 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 ............. ~r · Is adequate wel lbore 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 ~-~ ps ig ..... Does choke man i fold comply w/API RP-53 (May 84) ...................... ~ Is presence of H2S gas .probable ...................................... 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 ncmber of contact to supply weekly progress data ...... Lease & Well ~~ ~_~.>~70.' YES NO ,, Additional requirements ............................................. REMARKS INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE Add i t i ona I remarks: MERIDIAN' sM , ,,,,, WELL TYPE' Exp~)< Inj Red ri 11 Rev