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HomeMy WebLinkAbout196-019Pages 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. 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 [] Other COMMENTS: Scanned by: Bevedy~incent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Be~edy Dianna Vincent Nathan Lowell Date: Is/ Olq OR BEFO W Memorandum To: Well File: State of Alaska Oil and Gas Conservation Commissim 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 AP! numbers, permit numbers and well names did not specifically address expired or cancelled permits. This omission has caused some inconsistencies i the treatment of these kinds of applications for permit to ddil. Operators have asked us to adopt formal procedures for this class of permit application in order to prevent future database disparities. if a permit expires or is cancelled by an operator, the permit number of the subject permit will remair unchanged. The APl number and in some instances the well name reflect the number of preexistin! reddils 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 ddil. The AP! number for this cancelled or expired permit is modified so the eleven and twelfth digits is 9[ The well name for a cancelled or expired permit is modified with an appended xx. These procedures are an addendum to the AP! numbering methods descnbed in AOGCC staff memorandum "Multi-lateral (wellbore segment) Ddiling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician -~ARCO Alaska, Inc. Post Office Box 1003t~u Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 8, 1997 Mr. Steve McMains Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Cancellation of Approved Permit to Drill for 3H-27 Dear Mr. McMains: Per our discussion, I am writing this request to cancel the Permit to Drill for 3H- 27 in the Kuparuk River Unit. ARCO Alaska, Inc will not drill this well at all. If there are any questions, please call me at 263-4183. Sincerely, D. K. Petrash Drilling Engineer Kuparuk Drill Site Development DKP/skad CC: M. Zanghi Well File ATO- 1286 ATO-370 ALASKA OIL AND GAS CONSERVATION COMMISSION .-2 TONY KNOWLE$, GOVERNOF~ 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 January 31, 1996 Michael Zanghi Drill Site Development Supervisor ARCO Alaska, Inc. P C) Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 3H-27 ARCO Alaska, Inc. Pcrm/t No: 96-019 Sm'. Loc. 1044'FNL, 282'FWL, Sec. 12, T12N, R8E, UM Btmhole Loc. 866'FNL, 265 i'FEL, Sec. 03, T12N, R8E, UM Dear Mr. Zanghi: Enclosed is thc 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 wimess the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Tuckerman Babcock Commissioner BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o cncl. Department of Environmental Conservation w/o encl. ,STATE OF ~ ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of Work Drill X Redrill [-] 1 b Ty~ of Well Exploratory {--] Stratigraphic Test [-'1 Development Oil X Re-Entry r-I Deepen ~-1 Service E] Development Gas E] Single Zone X Multiple Zone 2. Name of Operator .5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 38' feet Kuparuk River Field 3. Address 6. Properly Designation Kuparuk River Oil Pool P. O. Box 100360, Anchoracje, AK 99510-0360 ADL 25532, ALK 2658 4. Location of well at sudace 7. Unit or property Name 11. Type Bond (see 2o AAC 25.025) 1044' FNL, 282' FWL, Sec. 12, T12N, R8E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 972' FNL, 2492' FEL, Sec. 3, T12N, R8E, UM 3H-27 #U-630610 At total depth 9. Approximate spud date Amount 866' FNL, 2651' FEL, Sec. 3, T12N, RSE, UM 2/1 5/96 $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 3H-18 12220' MD 866' @ TD feet 12.1' @ 450' feet 2400 6150' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.03.5(e)(2)) Kickoff depth 300' feel Maximum hole angle 67.6° Ma~m~m~r~,~ 1864 pslg At total depth (TVD) 3400 psig 18. Casing program Settin~l Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stave data) 24' 16' 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 12.25' 9.625' 40.0# L-80 BTC 5350' 41' 41' 5391' 3149' 1050 Sx Arcticset III & HF-ERW 760 Sx Class G 8'.5' 7' 26.0# L-80 BTCMOE 12179 41' 41' 12220' 6150' 150SxClassG HF-ERW Top 500' above Kuparuk lg. To be completed for Reddll, 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 deplh True Vertical depth Structural Conductor .. Sudace ~.~, ......... · ~. Intermediate · --" Production Liner J,~N '~ .~ '~'.~ Perforation depth: measured true vertical ~-~ Oi!~ ~;: C:-,~.._:,:,.;., ¢.0~S... 20. Attachments Filing tee X Property plat r-] BOP Skelch X Diverter Sketch X A~qO~h'~i~]~program X Drilling fluid program X Time vs depth plot [-i Refraction analysis E] Seabed report E] 20 AAC 25.050 requirements X 21. I hereby certify that thelforegoing is true and correct to the best of my knowledge Signed ~/[/2,. Title Drill Site Develop. Supv. Date ' 5A~01. u~ ..~b C°m misiion Use Ona~/dl~ /F Permit Number I Approv Mud I~g r~eq~uired [-1 Yes See cover letterlor~ No ~ other requirements Conditions of approval Samples required r-] Yes .~ No Hydrogen sulfide measures [~ Yes E] No Directional survey required ~'1 Yes [-1 No Required working pressure lor BOPE 2M [~ 3M D 5M BI 1OM BI 15M Other: ~ ~ .-..-~_..,.- .~. . by order of Approved by / ,, ..... ' "" ~ "- / ~'~' Commissioner the commission Date-" / Form 10-401/Rev. 7-24-89 :riDlicate .....--~-. I , . . , . , . ge 10. 11. 12. 13. 14. 15. 16. 17. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 3H-27 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (5,391')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE to 3000 psi. 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 (12,220') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing string. (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.) ND BOPE. NU tubinghead & either full opening valve. Run cased hole cement bond logs. Secure well and release rig. Move in and rig up Nordic #1. Install and test BOPE. Pressure test 7" casing to 3500 psi. Run completion assembly. Set packer and pressure test tubing and annulus. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig in preparation for perforating. JAN 1 8 1996 Alaska ~ & Gas Cons. Commission Anchorage , . . . . . e . 10. 11. 12. 13. 14. 15. 16. 17. GENERAL DRIllING PROCEDURE KUPARUK RIVER FIELD 3H-27 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (5,391')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE to 3000 psi. 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 (12,220') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing string. (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.) ND BOPE. NU tubinghead & either full opening valve. Run cased hole cement bond logs. Secure well and release rig. Move in and rig up Nordic #1. Install and test BOPE. Pressure test 7" casing to 3500 psi. Run completion assembly. Set packer and pressure test tubing and annulus. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig in preparation for perforating. DRILLING FLUID PROGRAM Well KRU 3H-27 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% Weight up to TD 11.5 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% 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 General Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.O33. 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 1,864 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 3H-27 is 3H-18. As designed, the minimum distance between the two wells would be 12.1' @ 450' MD. Drilling Area Risks- Risks in the 3H-27 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. 7" casing will be topset above the Kuparuk and Nordic Rig #1 will drill out a 6-1/8" hole, and run a 5" liner to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 11.5 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 9-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. JAN ~ ~ ~,996 Alaska 0il & Gas Cons. Commission Anchorage DRILLING FLUID PROGRAM Well KRU 3H-27 Density PV YP Viscosity Initial Gel 10 Minute Gel ~API 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% Weight up to TD 11.5 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% 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 General 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 1,864 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 3H-27 is 3H-18. As designed, the minimum distance between the two wells would be 12.1' @ 450' MD. Drilling Area Risks: Risks in the 3H-27 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. 7" casing will be topset above the Kuparuk and Nordic Rig #1 will drill out a 6-1/8" hole, and run a 5" liner to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 11.5 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 9-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. ANNULAR PUMPING OPERATIONS Well KRU 3H-27 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. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 3H-27 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface, if the surface shoe is within 200' TVD of the top of the hydrocarbons. Alternatively, if the hydrocarbons are far below the shoe then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 3H-27 be permitted for annular pumping occurring as a result of the drilling project on DS 3H, per proposed regulations 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Please reference the enclosed directional drilling plan for other formation markers in this well. A list of all publicly recorded wells within 1/4 mile of the disposal operation is included in this permit application. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The 3H surface casing shoes will be set +_200' vertical below the base of the West Sak into the heart of the shales. The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1500 psi 3H-27 Max Pressure = 3465 psi The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. OD Wt Conx Collapse 85% of Burst 85% of (in) (Ib/ft) Grade Range Type (psi) Collapse (psi) Burst 9.625 40 L-80 3 BTC 3090 2627 5750 4 8 8 8 7.000 26 L-80 3 BTC-M 5410 4 5 9 9 7240 6154 Fluids to be disposed of in subject annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.254 (g) (1). ~~,~.tV '~-O JAN 1 o~ 1~96 Alaska 0il & Gas Cons, Commission Anchorage ANNULAR PUMPING OPERATIONS Well KRU 3H-27 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. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 3H-27 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface, if the surface shoe is within 200' TVD of the top of the hydrocarbons. Alternatively, if the hydrocarbons are far below the shoe then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 3H-27 be permitted for annular pumping occurring as a result of the drilling project on DS 3H, per proposed regulations 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Please reference the enclosed directional drilling plan for other formation markers in this well. A list of all publicly recorded wells within 1/4 mile of the disposal operation is included in this permit application. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The 3H surface casing shoes will be set +__200' vertical below the base of the West Sak into the heart of the shales. The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1500 psi 3H-27 Max Pressure = 3465 psi The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. OD Wt Conx Collapse 85% of Burst 85% of (in) (Ib/ft) Grade iRange Type (psi) Collapse (psi) Burst 9.625 40 L-80 3 BTC 3090 2627 5750 4 8 8 8 7.000 26 L-80 3 BTC-M 5410 4599 7240 6154 Fluids to be disposed of in subject annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.254 (g) (1). ARCO ALASKA, Inc. Pad 3R 27 slot #27 Kuparuk River Unit North Slope, Alaska CLEARANCE REPORT by Baker Hughes [NTEQ Your ref : 27 Version #10 Our ref : prop1449 License : Date printed : 12-Jan-96 Date created : 27-0ct-95 Last revised : 12-Jan-96 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 24 56.740,w150 0 47.688 Slot location is nTO 24 46.472,w150 0 39.421 Slot Grid coordinates are N 6000613.087, E 498655.349 Slot local coordinates are 1044.00 S 282.00 E Reference North is True North Main calculation performed with 3-D Minim~m~ Distance method Object wettpath PGMS <O-8167'>,,1,Pad 3H PGMS <O-9555'>,,3,Pad 3H PGMS <O-8095'>,,4,Pad 3H PC~tS <0-7155~>,,5,Pacl 3H PC~S <O-7987~>,,6,Pad 3H PGMS <O-8~20'>,,7, Pad 3H PC.~IS <O-5881'>,,8, Pad 3H PC.~tS <0-7510'>,,9,Pad 3H PC.~S <O-8350'>,,2,Ped 3H PC.~tS <O-6785'>,,10,Pad 3H PGNS <O-7750'>,,11,Pad 3H PC~IS <O-8650'>,,19,Pad 3H P(~4S <O-9770'>,,16,Ped 3H PC-NS <O-&514'>,,17, Pad 3H PC.~S <O-8460'>,,15,Ped 3H PGHS <O-8250'>,,14,Pad 3H PGHS <O-7298'>,,12,Pad 3H PC.~S <O-7370'>,,13,Ped 3H PGHS <O-102~4'>,,22,Pad 3H PGMS <O-11346~>,,21,Ped 3H PMSS <1506-2076~>,,20,Pad 3H PNSS <1622-4449~>,,20,Pad 3H PC.~tS <O-9050~>,,20,Pad 3N PNSS <1506-3878~>,,20,Pad 3H Pr.~s <O-10293~>,,18,Pad 3H PMSS <1743-6660~>,,26,Pad 3H PGMS <O-10730~>,,31~Pad 3H PGMS <O-12410~>,,25,Pad 3H PGMS <O-9360~>,,23,Ped 3H Closest approach with 3-D minim[zndistance method Last revised Distance M.D. Diverging from M.D. 13-Nov-91 502.1 40.0 120.0 13-Nov-g1 450.8 325.0 12220.1 13-Nov-91 427.0 300.0 12180.0 13-Nov-91 402.0 300.0 300.0 13-Nov-91 378.0 100.0 120.0 13-Nov-g1 351.4 325.0 325.0 13-Nov-91 325.3 325.0 325.0 13-Nov-91 303.0 120.0 12220.0 13-Nov-91 475.3 325.0 325.0 13-Nov-91 278.1 60.0 12220.1 13-Nov-91 188.0 100.0 10240.1 13-Nov-91 12.1 100.0 450.0 13-Nov-91 63.0 220.0 220.0 13-Nov-91 38.1 100.0 300.0 13-Nov-91 88.1 100.0 300.0 13-Nov-91 113.2 100.0 120.0 13-Nov-91 163.0 20.0 10080.0 13-Nov-91 137.5 300.0 300.0 13-Nov-91 87.0 220.0 220.0 13-Nov-91 62.0 100.0 425.0 13-Nov-91 34.5 500.0 500.0 13-Nov-91 34.5 500.0 500.0 13-Nov-91 34.5 500.0 500.0 13-Nov-91 34.5 500.0 500.0 13-Nov-91 12.1 450.0 450.0 20-Mar-94 339.7 300.0 300.0 20-Apr-94 75.0 0.0 0.0 19-Apr-94 1~2.2 100.0 350.0 31-0ct-95 18.0 525.0 525.0 24 Version #8,,24,Pad 3H 28 Version ~9,,28,Pad 3H 12-Jan-96 50.0 300.0 300.0 12-Jan-96 75.0 300.0 300.0 ARCO ALASKA, !nc. Pad 3H 27 slot #27 Kuparuk River Unit North SLope, ALaska CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 27 Version #10 Our ref : prop1449 License : Date printed : 12-Jan-96 Date created : 27-0ct-95 Last revised : 12-Jan-96 Field is centred on nTO 16 18.576,w150 5 56.536 Structure is centred on nTO 24 56.740,w150 0 47.688 Slot location is n70 24 46.472,w150 0 39.421 Slot Grid coordinates are N 6000613.087, E 498655.349 Slot local coordinates are 1044.00 S 282.00 E Reference North is True North Main caLculation performed with 3-D Minimtzn Distance method Object wet lpath PGHS <O-8167'>,,1oPad 3H P13~15 <O-9555'>,,3,Pad 3H PG~tS <O-8095'>,,4,Pad 3H PI3NS <O-7155'>,,5,Pad 3H PI3~S <O-7987'>,,6,Pad 3H PI3NS <O-8620'>,,7, Pad 3H PGHS <O-6881'>,,8,Pad 3H P(~tS <O-7310'>,,9,Pad 3H P(;HS <O-8350'>,,2,Pad ~H PGH$ <O-6785'>,,10,Pad ~H P(~IS <O-7750'>,,11,Pad 3H P(~IS <O-8650'>,,19,Ped 3H P(~tS <O-e770~>,,16,Pad 3H P(~S <O-8614~>,,17, Pad 3H PG#S <O-8460,>,,15,Ped 3H P(~NS <O-8250'>,,14,Pad 3H P(~tS <O-72~8'>,,12,Pad 3H PGNS <O-7370'>,,13,Pad 3H PGNS <O-10234'>,,22,Pad 3H PGNS <O-11346'>,,21,Pad 3H PMSS <1506-2076~>,,20,Pad 5H PMSS <1622-444g~>,,20,Pad 3H Pi;NS <O-gOSO~>,,20,Pad 3H PMSS <1506-3878'>,,20,Pad 3H PG#S <O-10293'>,,18,Pad 3H PMSS <1?43-6660'>,,26,Pad 3H PGNS <O-10730'>,,31,Pad 3H PGNS <O-12410'>,,25,Pad 3H PC.~tS <O-9360'>,,23,Pad 3H Closest apgroach with 3-D minim~ distance method Last revised Distance M.D. Diverging from M.D. 13-Nov-91 502.1 40.0 120.0 13-Nov-91 450.8 325.0 12220.1 13-Nov-91 427.0 300.0 12180.0 13-Nov-91 402.0 300.0 300.0 13-Nov-91 378.0 100.0 120.0 13-Nov-91 351.4 325.0 325.0 13-Nov-91 325.3 325.0 325.0 13-Nov-91 303.0 120.0 12220.0 13-Nov-91 475.3 325.0 325.0 13-Nov-91 278.1 60.0 12220.1 13-Nov-91 188.0 100.0 10240.1 13-Nov-91 12.1 100.0 450.0 13-Nov-91 63.0 220.0 220.0 13-Nov-91 38.1 100.0 300.0 13-Nov-91 88.1 100.0 300.0 13-Nov-91 113.2 100.0 120.0 13-Nov-91 163.0 20.0 10080.0 13-Nov-91 137.5 300.0 300.0 13-Nov-91 87.0 220.0 220.0 13-Nov-91 62.0 100.0 425.0 13-Nov-91 34.5 500.0 500.0 13-Nov-91 34.5 500.0 500.0 13-Nov-91 34.5 500.0 500.0 13-Nov-91 34.5 500.0 500.0 13-Nov-91 12.1 450.0 450.0 20-Mar-94 339.7 300.0 300.0 20-Apr-94 75.0 0.0 0.0 19-Apr-94 172.2 100.0 350.0 31-0ct-95 18.0 525.0 525.0 24 Version #8,,24,Pad 3H 28 Version #9,,28,Pad 3H 12-Jan-96 50.0 300.0 300.0 12-Jan-96 75.0 300.0 300.0 6OO 0 o 0 0 .. _ ~ 600 _ _ 1200_ - (D 18oo_ 0 24OO_ · -I.-- - (D 3000_ --  3600_ I-- - 4200_ I - V 4800_ Created by : jones For: D PETRASHI Date plotted : 12-Jan-96 Plot Reference is 27 Version ~10. Coordinates ore in feet reference slot ~27. [True Vertical Depths are reference RKB (Parker ~245).i 6000_ 6600 TD LOCATION: 866' FNL, 2651' FEL SEC. :.'3, T12N, RSE ARCO ALASKA, Inc. Structure : Pad SH Well : 27 Field : Kuparuk River Unit Location : North Slope, Alaska < W e s f Scale 1 ' 500.00 8400 7800 7200 6600 6000 5400 4800 4200 3600 3000 2400 1800 1200 600 0 600 N 56.4 DEG W e?0' TARGET LOCATION: 972' FNL, 2492' FEL SEC. 3, T12N, RSE TARGET TVD=5923 TMD=Jlg24 DEP=9670 NORTH 5352 WEST 8054 6000 _ _5400 _ 4800 4200 3600 _ _3000 RKB ELEVATION: 79' . o~-v _ 1200 --.., KOP TVD=300 TMD=300 DEP=O .o o~° °~ - 6.00 ~'18.00 BUILD 3 DE6; / 100, ,,,24.0o %. .-'. \..~.oo 'e _ o .. \36.00 · 42'4~00 B/ PERMAFROST TVD-1629 TMD=1770 DEP=538 - ~40.¢~i00 T/ UGNU SNDS WD=1929 TMD=2251 DEP=913 _600 o ~ B/ W SAK SNDS TVD=2949 TMD=4867 DEP=3321 I SEC. 12, T12N, RSE TVD=3149 TMD=5391 DEP=5805 ..... 6?.56 DF:,G W0'5~1 '58 0000.0~DROPu 2 DEG / 100' .00 0 ..... T/ UNiT C W~=8927 4U DtYG T/ UNI~ ^ W~=5989 TUD=~197~ ~EP=9700 ~/ KUP SNDS TVO:S~97 TMD=~2020 ~EP:9782 TD / ?" OSC, P~ TVD=6iS0 Ti, ID=t2220 DEP=g86t 0 600 ~200 1800 24o0 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 Scale 1 : 500.00 Vertical Section on 303.60 azimuth with reference 0.00 N, 0.00 E from slot //27 _2400 ]~] _ 0 _1800 '=~ · ~ · - ~ 600 ~o 0 · 600 _ _ 1200. ~ 1800. U 2~oo -ii ~) 3000 ~ 3600_ I--- - 4200_ V 4800_ 54ooq {Cc~::~ed by : jones For: D PETP, ASHi O<3te plotted : 12-Jan-96 Plot Reference is 27 Version [Coordinotes ore in feet reference slot #27. iTrue Vertical Depths ore reference RKB (Porker ~245). TD LOCATION: 866' FNL, 2651' FEL SEC, 3, T12N, RBE ARCO ALASKA, Inc.i Stru¢turo : Pad 31-1 Woll : 27 I Field : Kupnruk Ri¥,r Unit Lo¢ofion : Nodh Slop,, Alaska i < - - W e s t soo, , · ;oo.oo 8400 7800 7200 6600 6000 5400 4800 4200 5600 5000 2400 1800 1200 600 0 600 N 56.4 DEG W 9670' (TO TARGET) TARGET LOCATION: 972' FNL, 2492' FEL SEC. 3, T12N, R8E TARGET TVD=5923 TMD= 11924 DEP=9670 NORTH 5352 WEST 8054 RKe ELE-VATIO~I: 79' ,~' o~''v _ 1200 KOP TVD=300 TMD=300 DEP=O ~.oo ~ _~ ~ - %,42.. ~. ,~. B/ PERMAFROST WD=1629 TMD=1770 OEP=538 - -- ~54 ~ - 600 o ~&~.~ T/ UGNU SNDS ~D=1929 TMD=2251 DEP=913  c ~e=20~5 TU~=2552 ~EP=~ ~T/ W ~ SNDS ~D=~459 TUD=~5~4 ~EP=2~4 I SU~AC[ LOCATION: 9 5/8" CSG PT ~D=3~49 TMD=5591 DEP=3805 67.56 DEG BEGIN ANGLE DROP WD=5117 TMD=10546 DEP=8569 6600 B/ HRZ ~~D=11730 DEP=95411R~O.O0 K-1 ~RKER ~D=SB54ATMD=11832 DEP=9610 46.00 TARGET ANGLE T~6ET - T/ UNIT ~°°°d' 40 DEG TSUNIT C ~D:5927 TMD=11929 OEP=9673 UNIT A ~D=5959 TMD=11971 DEP=9700 ~/ KUP SNDS ~D=5997 TMD=12020 DEP=9732 TD / 7" CSG ~ T~=6150 TMD=12220 DEP=9861 0 600 1200 1800 2~0 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 Scele 1 - 300.00 Vertical Section on 303.60 ~zimuth with reference 0.00 N, 0.00 E from slot ~27 6000 _ _5400 _4800 _ _4200 - /h _3600 _ _3000 _ _2400 Z O _1800 I - 25'- Created by : jones For: D PETEASH Date plotted : 12-Jan-fl6 Plo[ Reference is 27 Version ~10. Coordinates ore in feet reference slot ~27. True Vertical Depths ore reference RKB (Porker ~245). /X I I 280_ _ 260_ _ 240_ _ 220_ _ 200_ I 100_ 0 ARCO ALASKA, Inc. Structure : Pad SH Well : 27 Field : Kuparuk River Unit Location : North Slope, Alaska < Wesf ~co,~ ~. ~o.oo 260 240 220 200 180 160 140 120 1 O0 80 60 40 20 0 20 40 60 1900 1800 1600 1700 1200 8O 11o0 60 _ 40_ _, 0 _ 1500 1400 100 2800 1300 CO 60  1500 1100 ~~ 1000 11oo~ 2700 ~0 90o 1000~ 1300 2600 ~ 1200~  2500 110o 170o 9O0 O0 ~oo 8oo ,1500 ~ 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 260 240 220 200 180 160 140 120 100 80 60 1000 ~oo 900 ,oo 'oo /1200 $00 / 600 ~ ~ /,ooo /900~800 ~ _280 _26O _ _240 _ _220 _ _200 _ _180 160 140 I I _120 Z _100 0 - 80 , _ ~0 40 2O 0 20 _.,. 40 " ~0 CD Wesf 40 ~ 20 0 20 40 60 Scale 1 · 10.00 Icr~o~o b~ : Jo~ For: D PETRAMHi IPlot. Refe~n~ ~ 27 Ve~ ~10. }Coord[net ..... in feet ret ....... lot ~27. Tme Vedicel Depths ere reference RKB (Pe~er ~245). ARCO ALASKA, Inc. Structure : Pad SH Well : 27 Field : Kuporuk River Unit Location : North Slope, Alaska _ 1 'Xx1500 1900 1000~ 1300 260_ _ 240_ 22O_ _ 200_ 1 < West Scale 1' ~0.00 260 240 220 200 180 160 140 120 1 O0 80 60 40 20 0 20 40 60 120. 26OO 1800 100 2500 1000 8O 6O °°l c5 2o .. c) 1201 1700 1200 9O0 800 900 1000 100 '.~0 1500 ~~1oo~,~~ 40¸ 20 l~'~'~"~"'--1400 I I I I I I I ! I I I i I t I ' I I I I I [ 260 240 220 200 i80 160 140 1~0 1 O0 810 6~0 410 ¢ 210 <-- West lO0O 9OO 900 ,oo zOO /1200 600 / 600 ~ 1000 /"oo ~ 0 20 40 60 Scale 1 ' 10.00 _280 _ _260 _ _240 _ _220 _ _200 __180 _160 _140 I - I _120 - _100 8O _ _ 60 20 4-0 © 60 CD A I I Oea~ed by : jone~ For: D PETRASH iDote plotted : 12--Jan--96 IPIot Reference is 27 Version ~[10. ICoordinotes ore n feet reference slot ~27. ,True Vertlcol Depths ere reference RK8 (Porker 1245). ARCO ALASKA, Inc. Structure : Pod 3H Well : 27 Field : Kuparuk River Unit Location : Nodh Slope, Alaska <-- West sco, ,. o.oo 880 840 800 760 720 680 640 600 560 520 480 440 400 360 320 280 240 200 720 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 680_ 0 O0 -- I 1900 1800 0 21oo x. ,~oo ~ 1700 1~0 2000 2000 20( 72O _ _680 ~640 f600 _560 _ _520 lg00 5OO _480 _ _440 A - I I 1600 1400 1500 120 0 0 1700 80 80 ~ 2000 -- '' ~ 40 ~500 hO '-~ 40 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 880 840 800 760 720 680 640 600 560 520 480 440 400 360 320 280 240 200 <-- West o.oo 1 Creat~ by : jone~ For: D PETRASH[ Dote plotted : 12--Jan-96 I Plot Reference ~s 27 Ve~ion ~10. ~ Coordin~es ore in feet reference slot ~27. ~ Tree Ve~col Depths ore reference RKB (Po~er ~245).~ 720 . . _ 680_ _ 640 600 52O 320 0 28{ 20( ARCO ALASKA, Inc. Structure : Pad SH Well : 27 Field : Kuparuk River Unit Location : Nor-Ih Slope, Alaska <-- West ~co,~.:o.oo 880 840 800 760 720 680 640 600 560 520 480 440 400 560 320 280 240 200 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 720 _640 ~ ~2oo ~ 1800 1700 ~ 2100 NlgO0 1700 N ~0 2000 2000 1500 19~ 160 120 .. -- 40 1400 130 60 1800 1300 2100 17o0 1600 2000 1500 _120 o - BO .. _ _ 40 0 I I Z I I I I I I I I I I I II II 880 840 800 760 720 680 640 600 560 520 480 440 400 360 ,320 280 240 200 < West ~o,~ ,. ~o.oo ICreated by : jones For: D PETRASHi IPlo[ Reference is 27 Yemlon ~10. ' jCoordin~es are in f~t reference slot ~27. Vertical ~pths ore reference RKB (Pa~er ~245). I ARCO ALASKA, Inc. Structure : Pad SH Well : 27 Field : Kuporuk River Unit Location : North Slope, Alaska A 1 900 8OO 700 1700t <-- West ~o,e ,. ~o.oo 2400 2300 2200 2100 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 1800 I I I I I I I I I I I I I I I t I I I I I I I I I I I I I I I I I I . 2600 4600 3C00 2600 28OO 28OO 2400 1800 _ _1700 _1600 _ _1500 _ _1400 _1500 _1200 LllO0 _1000 900 8OO 700 A I I Z O 600 2400 600 500 500 2000 400 2600 400 2200 300 0 200 .. ~ 100 300 2400 o ,-,'~ ~ ,,~f,~ 200 ~  100 0 C) 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 2400 2,300 2200 2100 2000 1900 1800 1700 1600 1500 1400 1.300 1200 1100 1000 900 800 < West ~co,~ ~ · ~o.oo Creoted by : jone~ For: D PETRASH Dote plotted : 12-Jon-§$ Plot Reference is 27 Version f[10. Coordinotes ore tn feet reference slot ~27. True VerUcol Depths ore reference RKB (Porker ~245). A2CO ALASKA, Inc. 120, A 1 900 800 700 Structure : Pod 5H Well : 27 Field : Kuparuk River Unit Locot[on : Horth Slope, Aloska West Scale 1' 50.00 2400 23O0 2200 2100 2000 1900 1800 1700 1600 15O0 140O 1300 12OO 11 O0 1000 900 8O0 1800/ 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~_~X I I I I I 17001 800 160I ]4600 130 BOO 3000 28OO 2600 26OO 3000 2800 24OO _1700 _1600 _1500 _1400 _1500 _1200 _1100 A _1000 I 9O0 0 800 .-~ 700 ~' 500 500 2200 2000 400 Z600 400 22OO 300 2OO 100 300 2400 o 200 ~  100 0 0 I I 2400 2,.300 2200 2100 2000 1900 1800 1700 1600 1.500 1400 1300 120011o0 100o 900 ,soo < Wesf · o.oo 1800 600 24O0 600 KUPARUK RIVER UN . 20" DIVERTER SCHEMATIC I 5 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. , IV~INTENANCE & OPERATION 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. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE 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 SPOOL WITH ONE 16' OUTLET. 5. ONE 16' HCR KNIFE VALVE WITH 16' DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTEFL DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20' - 2000 PSI ANNULAR PREVENTER. DKP 11/9/94 KUPARUK RIVER UN. 20" DIVERTER SCHEMATIC 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. 1. MAINTENANCE & OPERATION 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. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE 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 SPOOL WITH ONE 16' OUTLET. 5. ONE 16' HCR KNIFE VALVE WITH 16' DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. DKP 11/9/94 JAN 1 Oil & Gas Cons. r,]ommission Anch~'.)r~ge. 7 , 6 4 13 5/8" 5000 PS, 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 15(:X:) 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. I i I 1. 16" - 2000 PSI STARTING HEAD 2_ 11" - 3000 PSI CASING HEAD 11"-3000 PSI X 1:~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 ~ 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR BOP STACK TEST 1. Fill BOP STACK AND MANIFOLD WITH WATER. 2- CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THATTEST PLUG Will SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. ~ 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. & OPEN TOP PIPE RAMS AND CLOSE BO~FOM PIPE RAMS. TEST BoI-rOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 30(X) PSI 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 KOOMEY PUMP. 1;~ 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. VBRS WILL ACCOMODATE 3-1/2" TO 5-1/2" OR 5" TO 7" PIPE ODS AS APPROPRIATE, 7 ,6 , I I 4 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 13 5/8" 5000 PS. ,..-30P 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 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 AND 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 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'FI-OM PIPE RAMS. TEST BOI-I'OM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI 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 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. VBRS WILL ACCOMODATE 3-1/2" TO 5-1/2" OR 5" TO 7" PIPE ODS AS APPROPRIATE. INIT CLASS PROGRAM: exp [] dev ~. redrll [] serv [] wellbore seg [] ON/OFF SHORE 0 P~ e issued w/o hydrogen sulfide measure/Y N ~ed on potential o~ones . .... Y N Ly~~s zones. ........ Y N ~=~o-n-survey (if off-shore) ......... Y N /phone for weekly progress reports ..... Y N [exploratory only] ENGINEERING: COMMI SS ION: ~EW ~ ~{~$ DWJ Comments/Instructions: .ring provided ............... .ng protects all known USDWs ........ 'uate to circulate on conductor & surf csg. uate to tie-in long string to surf csg . . 'er all known productive horizons ...... ns adequate for C, T, B & permafrost .... ~kage or reserve pit ............. .1, has a 10-403 for abndnmnt been approved. .lbore separation proposed .......... required, is it adequate .......... ~id program schematic & equip list adequate i~i~g'a~e~u~t~;'t~s~ ~o' ' '~ ' ~slgi~ ,ld complies w/API RP-53 (May 84) ...... :cur without operation shutdown ....... of H2S gas probable ............ ttached ................... ~ N appropriate ................ ~ N ~ame and number ............... ~. N in a defined pool .............. ~ N proper distance from drlg unit boundary. . ~ N proper distance from other wells ...... ~ N ~reage available in drilling unit ...... ~ N is wellbore plat included ......... ~ N y affected party .............. ~ N appropriate bond in force ......... ~ N e issued without conservation order ..... ~ N e issued without administrative approval.. ~ N e approved before 15-day wait ........ ~ N REMARKS