EP3219906B1 - Verfahren für hydraulisches verzögerungsspitzenventil - Google Patents

Verfahren für hydraulisches verzögerungsspitzenventil Download PDF

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Publication number
EP3219906B1
EP3219906B1 EP17165433.8A EP17165433A EP3219906B1 EP 3219906 B1 EP3219906 B1 EP 3219906B1 EP 17165433 A EP17165433 A EP 17165433A EP 3219906 B1 EP3219906 B1 EP 3219906B1
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EP
European Patent Office
Prior art keywords
casing
pressure
piston
time delay
fluid
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Active
Application number
EP17165433.8A
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English (en)
French (fr)
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EP3219906A1 (de
Inventor
Kevin R George
James A. Rollins
John T. Hardesty
David S. Wesson
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Geodynamics Inc
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Geodynamics Inc
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Filing date
Publication date
Priority claimed from US14/840,473 external-priority patent/US9650866B2/en
Application filed by Geodynamics Inc filed Critical Geodynamics Inc
Publication of EP3219906A1 publication Critical patent/EP3219906A1/de
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Publication of EP3219906B1 publication Critical patent/EP3219906B1/de
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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • E21B34/08—Valve arrangements for boreholes or wells in wells responsive to flow or pressure of the fluid obtained
    • E21B34/085—Valve arrangements for boreholes or wells in wells responsive to flow or pressure of the fluid obtained with time-delay systems, e.g. hydraulic impedance mechanisms
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • E21B34/063—Valve or closure with destructible element, e.g. frangible disc
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • E21B34/10—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
    • E21B34/108—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole with time delay systems, e.g. hydraulic impedance mechanisms
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
    • E21B43/20—Displacing by water
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
    • E21B2200/06—Sleeve valves
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • E21B34/14—Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools

Definitions

  • An apparatus and method for providing a time delay in injection of pressured fluid into a geologic formation More specifically, it is a toe valve apparatus activated by fluid pressure that opens ports after a predetermined time interval to allow fluid to pass from a well casing to a formation.
  • Prior art tools also do not provide for a repeatable and reproducible time delays due to the uncontrolled manner of the tool opening. Therefore there is a need for a reliable, repeatable and reproducible time delay tool for opening connection to a formation in a controlled manner.
  • a sliding sleeve valve and method for assembly discloses the following: “A sliding sleeve valve and method for assembly is disclosed.
  • the valve comprises a segmented main body that is assembled from a top, middle and bottom segments.
  • the middle segment has flow apertures.
  • a closing sleeve is co-axially mounted in the assembled main body.
  • the closing sleeve has flow apertures that are intended to communicate with the flow apertures of the middle section when the valve is open.
  • the closing sleeve is sealed by seal means within the main body to prevent undesired fluid flow across the valve.
  • the seal means comprise primary, secondary and tertiary seals acting in cooperative combinations.
  • the seals comprise O-Ring and Vee-stack seals located within the body of the valve.
  • the sliding sleeve valve has a fluid pressure equalization means to permit equalization of fluid pressure across the valve before it is fully opened or fully closed in order to reduce wear on the seals.
  • the equalization means comprises a plurality of pressure equalization ports in the sliding sleeve that are intended to communicate with the main body apertures prior to the sliding sleeve apertures when opening and subsequent to the sliding sleeve apertures when closing.”
  • Prior art assembly and manufacturing of the valve as aforementioned comprises a number of individual components threadedly connected together with suitable seals.
  • the components of the tubular body may include top, middle and bottom segments, end couplings and coupling adapters that are connected together and integrated into a well casing.
  • the valve cannot withstand the torque specifications of a typical wellbore casing.
  • more number of segments and connections increases the propensity of leaks through the valve and therefore rendering the valve unreliable. Therefore, there is a need for a single piece mandrel or tubular body to withstand the torsional and torque specifications of the wellbore casing when the valve is threaded into the wellbore casing.
  • There is a need for a valve manufactured from a single piece mandrel provides for more reliability and reduces the propensity of leaks.
  • US2014/251619 describes an apparatus and method for providing a time delay in injection of pressured fluid into a geologic formation.
  • a toe valve is activated by fluid pressure that opens ports after a predetermined time interval to allow fluid to pass from a well casing to a formation, providing a time delay before fluid is passed through the ports, allowing multiple valves to be used in the same well casing and providing a focused jetting action to better penetrate a concrete casing lining.
  • CA2892128 also describes an apparatus and method for providing a time delay in injection of pressured fluid into a geologic formation.
  • US8267178 describes a valve for use in fracing through cement casing in a well that allows for flow of cement down the well during the cementing process and in the open position allows for fracing fluid to be directed through the cement casing for fracturing the formation adjacent the valve.
  • the valve is constructed so as to reduce the likelihood of the valve to jam as a result of cement or other foreign material.
  • US2012/279723 describes a downhole tool comprising an inner sleeve with a plurality of sleeve ports and a housing positioned radially outwardly of the inner sleeve and having a plurality of housing ports, with the housing and inner sleeve partially defining a space radially therebetween.
  • the space is occupied by a shifting sleeve.
  • a fluid path extends between the interior flowpath of the tool and the space.
  • a fluid control device occupies at least portion of the fluid path, and may selectively permit fluid flow, and thus pressure communication, into the space to cause a differential pressure across the shifting sleeve. When a sufficient differential pressure is reached, the shifting sleeve is moved from a first position to a second position, which opens the communication paths through the housing and sleeve ports between the interior flowpath and exterior of the tool.
  • Prior art systems do not provide for reliable time delay tools that open at high pressure for connection to a geologic formation.
  • Prior art systems do not provide for opening time delay tools with reverse acting rupture disks that resist plugging from wellbore debris and fluids.
  • Prior art systems do not provide for opening multiple time delay tools in a staged manner.
  • Prior art systems do not provide a time delay tool with a larger inner diameter.
  • Prior art systems do not provide for a short time delay tool that is controlled within a range of 0.5 seconds to 3 minutes.
  • Prior art systems do not provide for a long time delay tool that is controlled within a range of 60 minutes to 2 weeks.
  • Prior art systems do not provide for a long time delay tool that is controlled with a large pressure reservoir.
  • Prior art systems do not provide for a long time delay tool that is controlled with an extremely high viscosity fluid.
  • Prior art systems do not provide for a long time delay tool that is controlled stacked delay agents connected in series or parallel.
  • Prior art systems do not provide for a dual actuated controlled time delay valves manufacture from a single mandrel.
  • Prior art systems do not provide for a single actuated controlled time delay valves manufacture from a single mandrel.
  • Prior art systems do not provide for fracturing through a controlled time delay valves.
  • Prior art systems do not provide for detecting a wet shoe with a toe valve.
  • Prior art systems do not provide for removing debris from well with a multi injection apparatus.
  • Prior art systems do not provide for manufacturing a controlled time delay apparatus from a single mandrel that can carry all of the tensile, compressional and torsional loads of the well casing.
  • Prior art systems do not provide for a valve manufactured from a single piece mandrel for more reliability and reduces the propensity of leaks.
  • the objectives of the present invention are (among others) to circumvent the deficiencies in the prior art and affect the following objectives:
  • a short time delay tool that is controlled within a range of 0.5 seconds to 3 minutes.
  • a controlled time delay apparatus Provide for manufacturing a controlled time delay apparatus from a single mandrel that can carry all of the tensile, compressional and torsional loads of the well casing.
  • valve manufactured from a single piece mandrel for more reliability and reduces the propensity of leaks.
  • a test method for checking an integrity of a wellbore casing is set out in claim 1.
  • the apparatus comprises a housing with openings, a piston, a stacked delay restrictor, an actuating device and a high pressure chamber with a hydraulic fluid.
  • the stacked delay restrictor is configured to be in pressure communication with the high pressure chamber and a rate of travel of the piston is restrained by a passage of the hydraulic fluid from the high pressure chamber into a low pressure chamber through the stacked delay restrictor.
  • the piston Upon actuation by the actuating device, the piston travels for an actuation time period, after elapse of the actuation time period, the piston travel allows opening of the openings so that the pressurized fluid flows through the openings for a port opening time interval.
  • a system as described herein may be utilized in the context of a controlled time delay method, wherein the system as described previously is controlled by a method having the following steps:
  • Described herein is an improved "toe valve” apparatus and method to allow fluid to be injected through ports in an oil or gas well casing wall section (and casing cement) into a geologic formation in a time delayed manner.
  • the apparatus in broad aspect, provides time-delayed injection of pressurized fluid through openings in a well casing section to a geological formation comprising:
  • the apparatus described herein represents several improvements over conventional pressure responsive devices improvements that will be appreciated by those of ordinary skills in the art of well completions.
  • the greatest limitation of current devices is that the sleeve or power piston of the device that allows fluid to flow from the casing to a formation (through openings or ports in the apparatus wall) opens immediately after the actuation pressure is reached. This limits the test time at pressure and in many situations precludes the operator from ever reaching the desired casing test pressure.
  • the present apparatus overcomes that limitation by providing a hydraulic delay to afford adequate time to test the casing at the required pressure and duration before allowing fluid communication with the well bore and geologic formation.
  • a second advantage of the apparatus described herein is that two or more valves can be installed (run) as part of the same casing installation.
  • This optional configuration of running two or more valves is made possible by the delay time that allows all of the valves to start metering before any of the valves are opened.
  • the feature and option to run two or more valves in a single casing string increases the likelihood that the first stage of the well can be fracture stimulated without any well intervention whatsoever.
  • Other known devices do not allow more than a single valve to operate in the same well since no further actuation pressure can be applied or increased after the first valve is opened.
  • a third significant advantage is that in the operation of the valve, the ports are opened slowly so that as the ports are opened (uncovered) the liquid is injected to the cement on the outside of the casing in a high pressure jet (resulting from the initial small opening of the ports), thus establishing better connection to the formation.
  • the fluid first jets as a highly effective pinpoint cutting jet and enlarges as the ports are opened to produce an effect of a guide-hole that is then enlarged.
  • Figure 1A represents a controlled time delay tool comprising an inner mandrel, 29 , that is inserted directly into the casing string and shows an overall external view of an embodiment of the apparatus of the invention. Slotted ports 28 through which fluid will be transported into the geologic formation surrounding the casing.
  • Figure 1B shows a cross section view of the apparatus of Figure 1A .
  • the integral one-piece design of the mandrel carries all of the tensile, compressional and torsional loads encountered by the apparatus.
  • the entire toe valve apparatus is piped into the casing string as an integral part of the string and positioned where perforation of the formation and fluid injection into a formation is desired.
  • the apparatus may be installed in either direction with no change in its function.
  • FIG 2 (a section of Figure 1B ) shows details of the apparatus.
  • a pressure activated opening device 23 preferably a Reverse Acting Disc but conventional rupture discs may be used for initiating a piston. Since the rupture disc is in place in the casing string during cementing it is very advantageous to have a reverse acting rupture disc that will not be easily clogged and not require extra cleaning effort.
  • the valve mandrel is machined to accept the opening device 23 (such as rupture discs) that ultimately controls actuation of the piston, 5 .
  • the opening piston, 5 is sealed by elastomeric seals ( 16 , 18 and 20 in Figure 2 and 45 , 47 and 49 in Figure 6 ) to cover the inner and outer ports, 25-27 and 28 , in the apparatus.
  • the openings 25-27 (and a fourth port not shown) shown in Figures 2 and 3 are open ports.
  • the ports 25-27 (and other inside ports) will have means to restrictive ports or a threaded and tortuous pathway, 50. This will impede rapid influx of well bore fluids through the rupture discs, 23 in Figure 2 and 52 in Figure 7 into the piston chamber 32.
  • the mandrel housing 54 is similar to mandrel housing 5 in Figure 2 and 52 is the rupture disc that corresponds to 23 in Figure 2 .
  • the mandrel housing 51 which is same as mandrel housing 6.
  • the piston, 5 has dual diameters ( Figure 6 shows the piston, 5 ( 46 and 48 ), with one section, 46 , having a smaller diameter at one end than at the other end, 48 .
  • This stepped diameter piston design will reduce the internal pressure required to balance out the pressure across the piston when the piston is subjected to casing pressure. This pressure reduction will increase the total delay time afforded by a specific restrictor. The resistance to flow of a particular restrictor is affected by the differential pressure across the component. By reducing the differential across the component, the rate of flow can be skillfully and predictably manipulated.
  • This design provides increased delay and pressure test intervals without adding a larger fluid chamber to the apparatus.
  • the dual diameter piston allows the pressure in the fluid chamber to be lowered.
  • the delay time will be increased by virtue of the fact that the differential pressure across a given restrictor or metering device will be reduced.
  • the pressure in the fluid chamber will be at or near the well bore pressure.
  • the lower end of the piston 46 smaller and the piston area adjacent to the fluid chamber, 48 , larger the forces will balance with a lower pressure in the fluid chamber. In this way it will be easy to reduce the fluid chamber pressure by 25% or more. fluid chamber. In this way it will be easy to reduce the fluid chamber pressure by 25% or more.
  • a series of outer sections 4 , 6 , and 8 illustrated in Figures 1A, 1B and 2 are threadedly connected to form the fluid and pressure chambers for the apparatus.
  • the tandem, 3, not only couples outer section 4 and piston 5 but also houses a hydraulic restrictor 22 .
  • the area, 32 , to the left of the piston, 5, is a fluid chamber and the area to the left of tandem 3 is the low pressure chamber that accommodates the fluid volume as it traverses across the hydraulic restrictor.
  • the chambers are both capped by the upper cap 8 .
  • the rupture disc 23 or 52 is the activation device that sets the valve opening operation into play.
  • the casing pressure is increased to a test pressure condition.
  • This increased pressure ruptures the rupture disc 23 or 52 and fluid at casing pressure (hydrostatic, applied or any combination) enters the chamber immediately below and adjacent to the piston 5 (in Figure 2 this is shown at the right end of piston 5 and to the left of valve 14 ).
  • This entry of fluid causes the piston 5 to begin moving (to the left in the drawings).
  • This fluid movement allows the piston to move inexorably closer to an open position. In actual lab and field tests a piston movement of about 11.4 cm(4.5 inches) begins to uncover the inner openings 25-27 and the outer openings 28 .
  • openings are initially closed or sealed off from the casing fluid by the piston 5 .
  • the slots, 28 are uncovered allowing fluid to flow through openings 25 , 26 and 27 through slots 28 .
  • Piston 5 surrounds the inter wall of the apparatus 29 .
  • Hydraulic fluid in the fluid chamber restrains the movement of the piston.
  • This flow restrictor controls the rate of flow of fluid from chamber 32 to chamber 34 and thereby controls the speed of the movement of the piston as it moves to the full open position.
  • Slots 28 in the apparatus mandrel that will be the passageway for fluid from the casing to the formation.
  • Figure 3 shows the position of piston 5 when "opened" (moved into chamber 32 ). Initially, this movement increases pressure in the fluid chamber to a value that closely reflects the hydrostatic plus applied casing pressure. There is considerable predetermined control over the delay time by learned manipulation of the fluid type, fluid volume, initial charging pressure of the low pressure chamber and the variable flow rate through the hydraulic restrictor. The time delay can be set as desired but generally will be about 5 to 60 minutes. Any hydraulic fluid will be suitable if capable of withstanding the pressure and temperature conditions that exist in the well bore. Those skilled in the art will easily be able to select suitable fluids such as Skydrol 500B-4TM.
  • This Back Pressure Valve or Pressure Relief Valve 42 may be selected based on the anticipated hydrostatic pressure. Back pressure valve (s) may also be placed in series to increase the trapped pressure. Another Back Pressure Valve or Pressure Relief Valve 44 may be placed downstream of the Fluid Metering Section 22 to ensure that only a minimum fluid volume can migrate from the Fluid Metering Section 22 to the Low Pressure Chamber 34 during transport, when deployed in a horizontal well bore or when inverted for an extended period of time. By selecting the appropriate pressure setting of these back pressure valves “slamming" (forceful opening by sudden onrush of pressurized fluid) of the flow control valve is reduced.
  • an apparatus as described herein will be piped into a casing string at a location that will allow fluid injection into the formation where desired.
  • the apparatus may be inserted into the string an either direction.
  • An advantage is that two or more of the valves of the invention may be used in the string. They will, as explained above, open to allow injection of fluid at multiple locations in the formation. It can also be appreciated by those skilled in the art how two or more of valves of the invention may be used and programmed at different time delays to open during different stages of well operations as desired (e.g. one or more at 5 minute delay and one or more at 20 minutes delay).
  • the apparatus may be configured so that an operator may open one or more valves (activating the sliding closure) after a five minute delay, fracture the zone at the point of the open valves, then have one or more valves and continue to fractures the zone.
  • the apparatus will be constructed of steel having properties similar to the well casing.
  • a prototype apparatus had the general dimensions of about 152 cm (60 inches) in length, with a nominal outside diameter of 16.5 cm (6.5 inches) and an inside diameter of 9.5 cm (3.75 inches). Other dimensions as appropriate for the well and operation in which the apparatus is intended to be used are intended to be included in the invention and may easily be determined by those of ordinary skill in the art.
  • Figure 8 represents the results of a test of a prototype of the apparatus. As shown, a 5-minute test shows constant pressure for 5 minutes while the piston movement uncovered openings in the apparatus. view of the stacked delay restrictor is further illustrated in FIG. 9b ( 0920 ).
  • the apparatus may comprise a piston that moves from a high pressure chamber to a low pressure chamber, when actuated.
  • the stacked delay restrictor ( 0902 ) is in communication with a high pressure chamber ( 0903 ), may comprise multiple stacked delay elements connected in a series, parallel or combination thereof.
  • the delay element may be a conventional hydraulic restrictor such as a ViscoJetTM.
  • the stacked delay restrictor allows fluid to pass from a high pressure chamber ( 0903 ) to lower pressure chamber ( 0901 ).
  • This flow restrictor controls the rate of flow of fluid from the high pressure chamber ( 0903 ) to the low chamber ( 0901 ) and thereby controls the speed of the movement of the piston ( 0904 ) as it moves to the full open position.
  • the number of delay elements may be customized to achieve a desired time delay for the piston to travel from a closed position to open an opening in housing of the apparatus.
  • the delay elements are connected in a parallel fashion as illustrated in FIG. 9c ( 0930 ).
  • An expanded view of the stacked delay restrictor with parallel delay elements ( 0902 , 0912 ) is further illustrated in FIG. 9d ( 0940 ).
  • the delay elements are connected in a series and parallel combination.
  • a time delay is greater than 60 minutes and less than 2 weeks.
  • the time delay may be controlled by manipulating the fluid type fluid volume in the delay elements, initial charging pressure of the low pressure chamber and the variable flow rate through the hydraulic restrictor.
  • the hydraulic fluid is solid at the surface that changes phase to liquid when in operation as a toe valve in the wellbore casing. Any hydraulic fluid will be suitable if capable of withstanding the pressure and temperature conditions that exist in the well bore.
  • the viscosity of the hydraulic fluid may range from 3 centistokes to 10,000 centistokes.
  • the time delay in the restrictor may be increased by addition of plugging agents.
  • the size and shape of the plugging agents may be designed to effect a longer or shorter time delay. For example, larger particle size plugging agents may delay the rate of travel of a piston as compared to smaller size plugging agents.
  • the delay elements may be designed as a cartridge that may be slide in and out of the restrictor.
  • the cartridge may have a form factor that is compatible with the restrictor.
  • the cartridge may be positioned and customized to achieve a desired time delay.
  • Table 1.0 illustrates an exemplary ratio of inner diameter (ID) to outer diameter (OD) in an exemplary controlled time delay apparatus.
  • the ratio of ID/OD ranges from 0.4 to 0.99.
  • a full bore version wherein the inner diameter of the apparatus is almost equal to the inner diameter of the wellbore casing enables substantially more fluid flow during production.
  • Table 2.0 illustrate the inner casing ID and outer casing ID corresponding to the Name column of Table 1.0. For example, a name of 4 1 ⁇ 2 refers to a casing OD of 4.5 in table 2.0.
  • Table 1.0 Name Outer Diameter (in) Inner Diameter (in) enables substantially more fluid flow during production.
  • Table 2.0 illustrate the inner casing ID and outer casing ID corresponding to the Name column of Table 1.0.
  • a name of 4 1 ⁇ 2 refers to a casing OD of 4.5 in table 2.0.
  • Table 1.0 Name Outer Diameter (cm(in)) Inner Diameter (cm(in)) 41/2 14.35 (5.65) 8.48 (3.34) 5 14.35 (5.65) 8.48 (3.34) 51/2 17.48 (6.88) 9.52 (3.75) 4 1 ⁇ 2 Full Bore x x 5 1 ⁇ 2 Full Bore 18.75 (7.38) 11.68 (4.6) Table 2.0 Casing OD Casing Weight Casing ID cm (in) Nm (lb/ft) cm (in) 11.43 (4.5) 18.30 (13.50) 7.70 (3.03) 11.43 (4.5) 15.73 (11.60) 7.90 (3.11) 13.97 (5.5) 31.18 (23.00) 9.60 (3.78) 13.97 (5.5) 27.12 (20.00) 9.90 (3.90) 13.97 (5.5) 23.95 (17.00) 10.23
  • an inner tool diameter and an inner casing diameter ratio ranges from 0.4 to 1.1.
  • the casing pressure is increased to a test pressure condition.
  • the piston ( 1001 ) is held in its place while the piston covers the openings ( 1002 ) in the housing
  • the casing pressure is increased to a test pressure condition which is generally the maximum pressure that a well casing is designed to operate.
  • a test pressure condition which is generally the maximum pressure that a well casing is designed to operate.
  • the increased pressure ruptures a pressure actuation device such as a rupture disc and fluid at casing pressure enters the chamber immediately below and adjacent to the piston ( 1001 ) into a high pressure chamber.
  • This fluid movement allows the piston to move inexorably closer to an open position.
  • the piston moves toward the openings in the housing of the apparatus.
  • the time the piston travels after an actuation event to just before uncovering a port may be considered actuation time period.
  • the restrained movement of the piston ( 1001 ) allows a time delay from the time the pressure actuation device is ruptured until the openings ("slots") ( 1002 ) uncovered for fluid to pass. This movement continues until the piston has moved to a position where the ports are almost open to fully open. Hydraulic fluid in the fluid chamber restrains the movement of the piston.
  • a stacked delay restrictor or a restriction element such as a ViscoJetTM may control the rate of flow of fluid from a high pressure chamber to a low pressure chamber and thereby control the speed of the movement of the piston as it moves to a full open position.
  • Figure 11a illustrates an exemplary pressure test with a controlled time delay toe valve apparatus.
  • the chart shows the pressure in the casing on the Y-axis plotted against time on the X-axis.
  • the pressure in the casing may be increased from an initial pressure ( 1101 ) to 80% of the maximum test pressure ( 1102 ).
  • a pressure actuating device such as a reverse acting rupture disk may rupture at 80-90% of the test pressure ( 1103 ) at time ( 1107 ).
  • the piston may be actuated then and begin to move as the pressure is further increased to max casing pressure (1104).
  • the actuation time period may be defined as the time taken by the piston to travel when the piston is actuated to the time the piston starts uncovering the housing openings.
  • the time of travel of the piston from time ( 1107 ) to time ( 1108 ) is the actuation time ( 1105 ).
  • the port opening time interval may be defined as the time taken by the piston to start opening the openings to completely open the openings.
  • the time of travel of the piston from time ( 1108 ) to time ( 1109 ) is the port opening time ( 1106 ).
  • the pressure in the casing may drop to the hydrocarbon formation pressure as the connection to the formation is complete.
  • the piston moves past the housing openings slowly in a controlled manner resulting in a jetting action for connection of the pressurized fluid to the formation.
  • the port opening time and the actuation time may be controlled by various factors including size of the high pressure chamber, hydraulic restrictor fluid, length of the hydraulic restrictor, plugging agents and design of the hydraulic restrictor.
  • the diameter of the plugging agent may range from 1 micron to 50 microns.
  • the port opening time interval may range from 1 second to 1 hour. According to a more preferred exemplary embodiment the port opening time interval may range from 0.5 second to 20 minutes. According to another preferred exemplary embodiment, the port opening time interval is almost 0 seconds.
  • FIG. 11b Similar to the chart in FIG. 11a ( 1140 ), a chart illustrating an instant open is generally illustrated in FIG. 11b ( 1160 ) wherein the piston make a connection to the formation instantaneously in a controlled manner.
  • the port actuation time period ( 1115 ) is relatively short and controlled as compared to the port actuation time period ( 1105 ) in FIG. 11a ( 1140 ).
  • the port actuation time period ranges from 0.5 seconds to less than 5 minutes.
  • the port actuation time period is almost zero or instantaneous.
  • the port actuation time period ranges from 60 minutes to less than 2 weeks.
  • the time delay or the actuation time period may be controlled by factors such as shorter hydraulic restrictor length, lower viscosity hydraulic restrictor fluid, and shorter high pressure chamber. To an operator controlling the fluid pressure from the surface, it would appear that the connection to the formation occurred instantaneously as the pressure response is too quick to detect. In this case, the connection to the subterranean formation occurs instantaneously in a controlled manner as compared to prior art methods wherein the piston is slammed to open the ports to the formation. According to a preferred exemplary embodiment, the apparatus makes connection to the formation instantaneously in a controlled manner.
  • FIG. 12a As generally illustrated in FIG. 12a ( 1210 ) a prior art rupture disk is prone to plugging with cement and other debris ( 1201 ). The plugging of the rupture disk ( 1210 ) may fluctuate the actuation pressure at which the rupture disk ruptures and may prevent actuation of the device. Therefore, there is a need for a rupture disk that functions as rated without plugging.
  • an exemplary reverse acting rupture disk may be used in a controlled time delay apparatus as a pressure actuating device.
  • the reverse acting rupture disk ( 1202 ) has the unique advantage of not getting plugged during cementing and other wellbore operations. This advantage results in the rupture disk to function as it is rated when compared to a conventional forward acting rupture disk which is susceptible to plugging.
  • FIG. 13 ( 1300 ), FIG. 14 ( 1400 ), FIG. 15a ( 1510 ), and FIG. 15b ( 1520 ) generally illustrate a jetting action of pressurized fluid from the wellbore casing to the hydrocarbon formation.
  • the ports in the mandrel align with the openings to produce a guided hole jet effect of the pressurized fluid through the openings.
  • the shape of the guided hole jet depends on the shape of the port in the piston and shape of the opening in the housing.
  • the valve may open at maximum pressure and an initial restricted flow area, which increases to maximum design flow area over time as the piston moves slowly across.
  • the shape of the port in the mandrel may be selected from a group comprising a circle, oval and a square.
  • the shape of the opening in the housing may be selected from a group comprising a circle, oval and a square.
  • FIG. 13 ( 1300 ) illustrates a jet that may be formed with a circle shaped opening ( 1303 ) in the housing and a circle shaped port ( 1304 ) in the mandrel ( 1302 ) when a piston uncovers the openings in the housing ( 1301 ).
  • FIG. 14 ( 1400 ) illustrates a jet that may be formed with an oval shaped opening ( 1403 ) in the housing and an oval shaped port ( 1404 ) in the mandrel ( 1402 ) when a piston uncovers the openings in the housing ( 1401 ).
  • FIG. 14 ( 1400 ) illustrates a jet that may be formed with an oval shaped opening ( 1403 ) in the housing and an oval shaped port ( 1404 ) in the mandrel ( 1402 ) when a piston uncovers the openings in the housing ( 1401 ).
  • FIG. 14 ( 1400 ) illustrates a jet that may be formed with an oval shaped opening ( 1403 ) in the housing and an oval shaped
  • FIG. 15a illustrates a jet that may be formed with an oval shaped opening ( 1503 ) in the housing and a circle shaped port ( 1504 ) in the mandrel ( 1502 ) when a piston uncovers the openings in the housing ( 1501 ).
  • FIG. 15b illustrates a jet that may be formed with a circle shaped opening ( 1513 ) in the housing and an oval shaped port ( 1514 ) in the mandrel ( 1512) when a piston uncovers the openings in the housing ( 1511 ).
  • a constant width slot or variable width slot such as a tear drop may also be used as an opening in the housing or a port in the mandrel. Any shape that is constant width as the piston travels may be used as an opening in the housing or a port in the mandrel. Similarly, a shape such as a tear drop that may become wider or narrower as the piston moves past the openings and the ports may be used as an opening in the housing or a port in the mandrel.
  • the flow area of the inner mandrel may be designed for limited entry applications so that flow is diverted to multiple injection points at high enough flow rate.
  • a preferred exemplary controlled time delay method with a controlled time delay apparatus may be generally described in terms of the following steps:
  • a preferred exemplary controlled time delay method with a controlled time delay apparatus may be generally described in terms of the following steps:
  • a dual actuating controlled time delay apparatus comprises dual controlled toe valves ( 1701 , 1702 ) for use in a wellbore casing.
  • Each of the dual toe valves (1701, 1702) is similar to the aforementioned toe valve apparatus in FIG. 1A and FIG. 1B .
  • Toe valve (first delay tool) ( 1701 ) may comprise a first piston ( 1704 ) that moves when actuated by a first pressure actuating device ( 1703 ), first openings ( 1705 ) in the housing and first ports ( 1707 ) in the mandrel.
  • toe valve (second delay tool) ( 1702 ) may comprise a second piston ( 1714 ) that moves when actuated by a second pressure actuating device ( 1713 ), second openings ( 1715 ) in the housing and second ports ( 1717 ) in the mandrel.
  • the first delay tool ( 1701 ) may be integrated into the well casing at a first location and the second delay tool (1702) may be integrated into the well casing at a second location.
  • the first location and the second locations may be determined by an open-hole log before casing is placed in a wellbore, seismic data that may include 3 dimensional formation of interest to stay in a zone, and a mud log.
  • the dual actuating controlled time delay apparatus may further comprise a third delay tool integrated into the wellbore casing at a third location.
  • the third tool may comprise a third housing with third openings, a third piston, and a third actuating device.
  • the number of delay tools aforementioned may not be construed as a limitation.
  • One ordinarily skilled in the art may use three or more delay tools that may be integrated into the wellbore casing to achieve staggered delay openings at various times. Other operations including pumping down tools, injecting fluid or plugging may be performed at any time while the delay tools are opening.
  • the dual actuating controlled time delay apparatus may be manufactured from an integral one-piece design of the mandrel that carries all of the tensile, compressional and torsional loads encountered by the apparatus.
  • the entire dual actuating controlled time delay apparatus may be piped into the casing string as an integral part of the string and positioned where perforation of the formation and fluid injection into a formation is desired.
  • the dual actuating controlled time delay apparatus may be installed in either direction with no change in its function.
  • Prior art systems do not provide for two or more toe valves in a single system due to the fact that the first connection to the formation releases all the pressure in the well casing, therefore making a potential second toe valve ineffective. This is caused by the tolerance in actuation pressure inherent in the actuation devices.
  • the time delays of individual toe valves are controlled independently so that multiple connection points to the formation are created. The effect of multiple connection points to the formation may result in increased connection efficiency and increased flow area to the formation. According to a preferred exemplary embodiment, the flow area may be increased by 50% to more than 1000%. According to a preferred exemplary embodiment, the time delays of the individual toe valves are the same.
  • the time delays of the individual toe valves are not equal.
  • a ratio of the first actuation time period and the second actuation time period ranges from 0.01 to 100.
  • a ratio of the first port open time interval and the second port open time interval ranges from 0.01 to 100.
  • one valve provides a fail-safe mechanism for connection to the formation.
  • the difference in rated pressures of the first actuating device ( 1713 ) and the second actuating device ( 1703 ) may be within 500 PSI. This is particularly important as the rated pressure of actuating devices such as rupture disks are rated within +- 500 PSI.
  • FIG.18 ( 1800 ) illustrates a perspective view of a controlled dual time delay controlled apparatus.
  • the controlled dual time delay controlled apparatus may be integrated into a wellbore casing ( 1901 ) as illustrated in FIG. 19 ( 1900 ).
  • the casing with the integrated dual control apparatus may be cemented with a cement ( 1902 ).
  • the apparatus may comprise two individually controlled time delay apparatus, a first delay tool ( 1903 ) and a second delay tool ( 1904 ).
  • the controlled dual time delay controlled apparatus may be integrated at a toe end of the casing.
  • the controlled dual time delay controlled apparatus may be integrated at a heal end of the casing.
  • a preferred exemplary controlled time delay method with a dual actuating controlled apparatus aforementioned in FIG. 17a ( 1710 ) may be generally described in terms of the following steps:
  • a single-actuating controlled dual time delay apparatus comprising dual time delay valves with pistons ( 2103 , 2113 ), a mandrel ( 2105 ), openings ( 2101 , 2111 ) and ports ( 2102 , 2112 ) for use in a wellbore casing.
  • the single-actuating controlled dual time delay apparatus may comprise a first piston ( 2103 ) and a second piston that move in opposite directions when actuated by a pressure actuating device ( 2104 ).
  • the first delay valve may be integrated into the well casing at a first location and the second delay valve may be integrated into the well casing at a second location.
  • the first location and the second locations may be determined by an open-hole log before casing is placed in a wellbore, seismic data that may include 3 dimensional formation of interest to stay in a zone, and a mud log.
  • the single actuating controlled time delay apparatus may further comprise a third delay tool integrated into the wellbore casing at a third location.
  • the third tool may comprise a third housing with third openings, a third piston, and an actuating device. It should be noted that the number of delay tools aforementioned may not be construed as a limitation. One ordinarily skilled in the art may use three or more delay tools that may be integrated into the wellbore casing to achieve staggered delay openings at various times.
  • two or more time delay valves may be actuated by a single actuating device.
  • the rate of travel of each of the pistons ( 2103 , 2113 ) in the apparatus may be controlled independently of each other.
  • the single-actuating controlled time delay apparatus may be manufactured from an integral one-piece design of the mandrel that carries all of the tensile, compressional and torsional loads encountered by the apparatus.
  • the entire single-actuating controlled time delay apparatus may be piped into the casing string as an integral part of the string and positioned where perforation of the formation and fluid injection into a formation is desired.
  • the single-actuating controlled time delay apparatus may be installed in either direction with no change in its function.
  • the time delays of individual toe valves are controlled independently so that multiple connection points to the formation are created.
  • the effect of multiple connection points to the formation may result in increased connection efficiency and increased flow area to the formation.
  • the flow area may be increased by 50% to more than 1000%.
  • the time delays of the individual toe valves are the same.
  • the time delays of the individual toe valves are not equal.
  • one valve provides a fail-safe mechanism for connection to the formation.
  • the other valve may act as a replacement or fail-safe to provide connection to the formation.
  • FIG.22 ( 2200 ) illustrates a perspective view of a controlled single-actuating dual time delay controlled apparatus.
  • the controlled single-actuating dual time delay controlled apparatus may be integrated into a wellbore casing.
  • the single-actuating may comprise two individually controlled time delay apparatus, a first delay tool and a second delay tool.
  • the controlled dual time delay controlled apparatus may be integrated at a toe end of the casing.
  • the controlled dual time delay controlled apparatus may be integrated at a heal end of the casing.
  • a preferred exemplary controlled time delay method with a single-actuating controlled dual time delay apparatus may be generally described in terms of the following steps:
  • a preferred exemplary fracturing method through a controlled time delay apparatus may be generally described in terms of the following steps:
  • the wiper plug designs used in today's horizontal well bores were initially developed for use in vertical well bores.
  • the horizontal well bores present a more challenging trajectory for the equipment due to the extended casing length and concentrated friction on only one side of the wiper plug.
  • the elastomeric fins of a wiper plug can become worn on one side and render incapable of sealing properly in the dimensions of the conventional shoe joint. This causes a phenomena called "wet shoe.”
  • the downfalls of having a wet shoe in a cemented wellbore casing include possible leak paths, lack of isolation, and no pressure integrity of the casing. Therefore, when a pressure casing integrity test fails, the cause of the failure is either a wet shoe or leak in the casing.
  • time delay injection valve or a toe valve with a ball seat enables detection of wet shoe when a ball or a restriction plug element dropped into the wellbore casing seats in the ball seat and seals the toe end to remediate the wet shoe.
  • the time delay injection valve is a hydraulic controlled time delay valve.
  • the time delay injection valve may be a hydraulic controlled time delay valve as illustrated in FIG. 1A .
  • An additional seat may be located below the valve, providing a means to test the toe, the valve and the well.
  • the time delay injection valve is a hydraulic controlled dual actuated time delay valve.
  • the time delay injection valve may be a hydraulic controlled dual actuated time delay valve as illustrated in FIG. 17a .
  • the time delay injection valve is a hydraulic controlled single actuated time delay valve.
  • the time delay injection valve may be a hydraulic controlled single actuated time delay valve as illustrated in FIG. 21a .
  • FIG. 25 ( 2500 ) generally illustrates a restriction plug element ( 2503 ) seated in a seating surface ( 2502 ) of a controlled time delay apparatus ( 2501 ).
  • the controlled time delay apparatus ( 2501 ) may be installed at a toe end of a wellbore casing.
  • the restriction plug element ( 2503 ) may be a ball that may be dropped to seat in the valve ( 2501 ).
  • the seated restriction plug element ( 2503 ) may seal any leaks past the restriction plug element ( 2503 ) in a toe ward direction, thereby enabling detection of a wet shoe in a wellbore casing.
  • a toe valve with a ball seat is used to isolate wet shoe failures from casing integrity failures.
  • a restriction plug element seated in a controlled time delay apparatus may be used to create the first stage in a perforation and fracturing operation.
  • FIG. 26 ( 2600 ) generally illustrates a perspective view of a restriction plug element seated in a seating surface of a controlled time delay apparatus.
  • the restriction plug element is degradable in wellbore fluids.
  • the restriction plug element is non-degradable in wellbore fluids.
  • the restriction plug element has a shape that may be selected from a group comprising a sphere, dart, oval, or cylinder.
  • a preferred exemplary wet shoe detection method through a controlled time delay apparatus with a ball seat may be generally described in terms of the following steps:
  • FIG. 28a illustrates a dual injection system with a time delay mechanism that may be used in a staged or sequential delay fashion with multiple injection points. As illustrated in FIG.
  • a first tool ( 2801 ) and a second tool ( 2802 ) may be conveyed with a wellbore casing or deployed into a wellbore casing ( 2805 ).
  • the wellbore casing may be lined with cement ( 2803 ) or open hole.
  • injection point one is open as illustrated in FIG 28b . ( 2820 ), and flow rate ramps up, carrying debris preferentially to clog injection point one. Injection point two then opens as illustrated in FIG. 28c ( 2830 ), allowing unobstructed flow to the wellbore.
  • Staggered sequential time delayed tools used in conjunction with already open connections or in sets by themselves) such that debris from cementing, perforation or other sources is preferentially drawn toward the tool that connects to the reservoir first, whether uphole or downhole from second tool, that opens leaving second tool to be free of debris with an improved connection to the reservoir.
  • fluid may be pumped into the well casing to move debris ( 2804 ) to the first injection point.
  • the second injection point may open after the first injection point plugs.
  • the dual injection apparatus may be manufactured from an integral one-piece design of the mandrel that carries all of the tensile, compressional and torsional loads encountered by the apparatus.
  • the entire dual injection apparatus may be piped into the casing string as an integral part of the string and positioned where perforation of the formation and fluid injection into a formation is desired.
  • the dual injection apparatus may be installed in either direction with no change in its function.
  • the first tool and the second tools are controlled time delay tools.
  • the first tool is a controlled time delay tool and the second tool is a perforating gun.
  • the first tool is a valve that may be actuated by a ball and the second tool is a controlled time delay tool.
  • the first tool and the second tools are valves that may be actuated by a ball. It should be noted that any combination of a controlled time delay tool, perforating gun, valve actuated by a ball may be used as the first tool and the second tool to create the first injection point and the second injection point.
  • two or more injections points may be used in a staggered fashion in order to collect debris before creating an obstruction free connection to the formation. This is particularly important for a liner hanger job wherein a liner hangs of the inside surface of the casing. If the casing is not substantially clean, the liner may not hang on to the inside surface.
  • a preferred exemplary debris removal method with a controlled dual injection apparatus comprising a first tool and a second tool may be generally described in terms of the following steps:
  • a preferred exemplary debris removal method with a controlled dual injection apparatus comprising a first delay tool and a second delay tool may be generally described in terms of the following steps:
  • a preferred exemplary debris removal method with a controlled apparatus comprising a first delay tool and a perforating gun may be generally described in terms of the following steps:
  • a preferred exemplary debris removal method with a staged time delay system comprising a first tool, a second tool and a third tool may be generally described in terms of the following steps:
  • the first tool is plugged with debris during the predetermined time.
  • the second tool and the third tool are controlled time delay valves.
  • the second tool and the third tool are actuated by a pressure of the pressurized fluid.
  • the first tool and the second tool are actuated by a first actuating device and the third tool actuated by a second actuating device.
  • the first tool and second tool are actuated by pressure and the third tool is actuated by a ball.
  • the ball is deployed into the wellbore casing after the first tool collects debris from the wellbore casing.
  • the system may further comprises a fourth controlled time delay tool which is configured to be collects debris through a fourth injection point along with the first injection point.
  • the sliding sleeve valve may be manufactured by installing a pressure actuating disk ( 23 ) such as a rupture disk or a reverse acting rupture disk onto the one piece mandrel ( 29 ).
  • a piston ( 5 ) may be installed onto the mandrel ( 29 ) to cover openings ( 25 ) in the mandrel ( 29 ).
  • the piston ( 5 ) may be installed from the first threaded end ( 41 ) towards the second threaded end ( 51 ) and hydraulically locking in place.
  • a first outer housing ( 6 ) may be slid over the piston ( 5 ) from the first threaded end ( 41 ) and stopping on a first shoulder ( 40 ).
  • a first outer housing ( 6 ) may be slid or glided over the piston ( 5 ) from the first threaded end ( 41 ) and stop on a first shoulder ( 50 ).
  • a high pressure chamber ( 32 ) may be installed with a hydraulic fluid from the first threaded end ( 41 ) and stop adjacent to said piston ( 5 ).
  • a restriction assembly ( 44 ) may be installed from the first threaded end ( 41 ) and stop adjacent to the high pressure chamber ( 32 ).
  • a second outer housing ( 4 ) may be slid or glided over the mandrel adjacent to the restriction assembly ( 44 ).
  • An end cap (43) is attached to the mandrel ( 29 ) and creating a low pressure chamber ( 34 ) adjacent to the restriction assembly ( 44 ).
  • the wellbore casing ( 60 ) may be threaded to the mandrel ( 29 ) with the threads ( 62 ). It should be noted that even though there is one threaded end ( 41 ) illustrated in the FIG.33 with threads ( 62 ), a second thread is made on the second threaded end ( 51 ) of the mandrel to customize the kind of thread used to thread into a wellbore casing. According to a preferred exemplary embodiment, the threads may be designed to casing torque specification.
  • a sliding sleeve valve for use in a wellbore casing comprises a mandrel with a first threaded end and a second threaded end.
  • the sliding sleeve valve may be conveyed with said wellbore casing.
  • the sliding sleeve valve may be installed on a toe end of said wellbore casing.
  • the mandrel may be a tubular annular single piece member.
  • the mandrel may be made from materials selected from a group comprising of steel, cast iron, ceramics or, composites.
  • the one piece integral piece enables the mandrel to carry the full torsional load 10,000 ft-lbs to 30,000 ft-lbs of a wellbore casing when the first threaded end and the second threaded end are threaded to ends of the wellbore casing.
  • the first threaded end and the second threaded end may be designed to carry the wellbore casing ( 60 ) specification.
  • the first threaded end and the threaded end are configured with threads that are configured to conform to the wellbore casing torque specification.
  • the sliding sleeve valve is assembled with components from one end only.
  • the rupture disk ( 23 ), the piston ( 5 ), the first outer housing ( 6 ), the high pressure chamber ( 32 ), the restriction assembly ( 44 ), the second outer housing ( 4 ) and the end cap ( 43 ) are all slid/glided or installed from the first threaded end ( 41 ) towards the direction of the second threaded end ( 51 ).
  • a plurality of components are installed longitudinally from either end of the mandrel. The components may be installed from
  • a plurality of components are installed on an outer surface of the mandrel.
  • the rupture disk ( 23 ), the piston ( 5 ), the first outer housing ( 6 ), the high pressure chamber ( 32 ), the restriction assembly ( 44 ), the second outer housing ( 4 ) and the end cap ( 43 ) are all slid/glided or installed on the outer surface of the mandrel ( 29 ).
  • the plurality of components are installed on an inner surface of the mandrel.
  • the plurality of components are installed on an inner surface of the mandrel and an outer surface of the mandrel.
  • said sliding sleeve valve is a controlled hydraulic time delay valve.
  • the controlled hydraulic time delay valve comprises dual time delay valves which are each actuated by dual actuating devices.
  • the controlled hydraulic time delay valve comprises dual time delay valves which are both actuated by a single actuating device.
  • the system described herein anticipates a wide variety of variations in the basic theme of time delay valves, but can be generalized a controlled time delay apparatus integrated into a well casing for injection of pressurized fluid into a subterranean formation, the apparatus comprising: a housing with openings, a piston, a delay restrictor, an actuating device and a high pressure chamber with a hydraulic fluid; the delay restrictor is configured to be in pressure communication with the high pressure chamber; a rate of travel of the piston is restrained by a passage of the hydraulic fluid from the high pressure chamber into a low pressure chamber through the delay restrictor; wherein upon actuation by the actuating device, the piston travels for an actuation time period, after elapse of the actuation time period, the piston travel allows opening of the openings so that the pressurized fluid flows through the openings for a port opening time interval.
  • the method described herein anticipates a wide variety of variations in the basic theme of implementation, but can be generalized as a controlled time delay method wherein the method is performed on a controlled time delay apparatus integrated into a well casing for injection of pressurized fluid into a subterranean formation, the apparatus comprising: a housing with openings, a piston, a delay restrictor, an actuating device and a high pressure chamber with a hydraulic fluid; the delay restrictor is configured to be in pressure communication with the high pressure chamber; a rate of travel of the piston is restrained by a passage of the hydraulic fluid from the high pressure chamber into a low pressure chamber through the delay restrictor; wherein pressurized fluid flows into the subterranean formation.
  • the present invention method anticipates a wide variety of variations in the basic theme of implementation, but can be generalized as a casing integrity test method wherein the method is performed with a controlled time delay apparatus the time delay apparatus comprising: a housing with openings, a piston, a restrictor, an actuating device and a high pressure chamber with a hydraulic fluid; the restrictor is configured to be in pressure communication with the high pressure chamber; a rate of travel of the piston is restrained by a passage of the hydraulic fluid from the high pressure chamber into a low pressure chamber through the restrictor; wherein upon actuation by the actuating device, the piston travels for an actuation time period, after elapse of the actuation time period, the piston travel allows opening of the openings so that the pressurized fluid flows through the openings for a port opening time interval; wherein the method comprises the steps of:
  • the present invention anticipates a wide variety of variations in the basic theme of oil and gas extraction.
  • the examples presented previously do not represent the entire scope of possible usages. They are meant to cite a few of the almost limitless possibilities.
  • This basic system and method may be augmented with a variety of ancillary embodiments, including but not limited to:
  • An embodiment wherein the delay restrictor is a cartridge comprising a plurality of delay elements connected as a series chain.
  • delay restrictor is a cartridge comprising a plurality of delay elements connected in a combination of series chain and a parallel chain.
  • hydraulic fluid has a viscosity ranging from 3 to 10000 centistokes.
  • hydraulic fluid further has plugging agents that are configured to further retard the rate of travel of the piston.
  • hydraulic fluid configured to change phase from a solid to a liquid.
  • An embodiment wherein the actuation time period ranges from greater than 60 minutes to less than 2 weeks.
  • An embodiment wherein the actuation time period ranges from 0.5 seconds to 60 minutes.
  • An embodiment wherein the actuation time period is ranges from 2 minutes to 3 minutes.
  • An embodiment wherein the port opening time interval ranges from 0.5 seconds to 20 minutes.
  • An embodiment wherein the apparatus is associated with an inner diameter and an outer diameter; the ratio of inner diameter to outer diameter ranges from 0.4 to 0.9.
  • An embodiment wherein the apparatus is associated with an inner tool diameter and the well bore casing is associated with an inner casing diameter ratio; the ratio of inner tool diameter to outer casing diameter ranges from 0.4 to 1.1.
  • actuating device has a rating pressure that is substantially equal to a pressure of the wellbore casing.
  • actuating device is a reverse acting rupture disk.
  • actuating device is a rupture disk.
  • mandrel further comprises ports; the ports are configured to align to the openings in the housing during the port opening time interval.
  • An embodiment wherein a shape of the openings in the housing is selected from a group consisting of: a circle, an oval, a triangle, and a rectangle.
  • a shape of the ports in the mandrel is selected from a group consisting of: a circle, an oval, a triangle or a rectangle.
  • a shape of the jet is determined by a shape of the ports and a shape of the openings.
  • the present invention system anticipates a wide variety of variations in the basic theme of time delay valves, but can be generalized a controlled dual time delay system for injection of pressurized fluid through a wellbore
  • a shape of the ports in the mandrel is selected from a group consisting of: a circle, an oval, a triangle or a rectangle.
  • a shape of the jet is determined by a shape of the ports and a shape of the openings.
  • the system described herein anticipates a wide variety of variations in the basic theme of time delay valves, but can be generalized a controlled dual time delay system for injection of pressurized fluid through a wellbore casing at a plurality of locations into a subterranean formation, the system comprising:
  • the method described herein anticipates a wide variety of variations in the basic theme of implementation, but can be generalized as a controlled dual time delay method for controlled injection of pressurized fluid into a subterranean formation at a plurality of locations, the method operating in conjunction with a controlled dual time delay system, the controlled dual time delay system comprising: a first delay tool integrated into the wellbore casing at a first location; the first delay tool comprises a first housing with first openings, a first piston, and a first actuating device; a second delay tool integrated into the wellbore casing at a second location; the second delay tool comprises a second housing with second openings, a second piston, and a second actuating device; wherein the controlled dual time delay method comprises the steps of:
  • the system described herein anticipates a wide variety of variations in the basic theme of time delay valves, but can be generalized a single-actuating controlled time delay system integrated into a wellbore casing for injecting pressurized fluid through the wellbore casing into a subterranean formation
  • the dual toe valve comprising: a housing with first openings and second openings, a first piston, a second piston, and an actuating device; wherein upon actuation by the actuating device, the first piston travels for a first actuation time period, after elapse of the first actuation time period, the first piston travel allows opening of the first openings so that the pressurized fluid flows through the first openings for a first port opening time interval; upon actuation by the actuating device, the second piston travels for a second actuation time period, after elapse of the second actuation time period, the second piston travel allows opening of the second openings so that the pressurized fluid flows through the second openings for a second port opening time interval
  • the method described herein anticipates a wide variety of variations in the basic theme of implementation, but can be generalized as a single-actuating controlled time delay method for controlled injection of pressurized fluid into a subterranean formation at a plurality of locations, the method operating in conjunction with a controlled single-actuating time delay toe valve integrated into a wellbore casing for injecting pressurized fluid through the wellbore casing into a subterranean formation, the single-actuating time delay toe valve comprising: a housing with first openings and second openings, a first piston, a second piston, and an actuating device; wherein the single-actuating time delay method comprises the steps of:
  • the system described herein anticipates a wide variety of variations in the basic theme of time delay valves, but can be generalized an apparatus integrated into a well casing, a time delay injection valve with a seating surface built into the valve; the seating surface is configured to seat a restriction plug element; whereby, when a leak is detected in the well casing during a casing integrity test, a restriction plug element is dropped to seat in the conforming seating surface to determine if the leak is due to the wet shoe.
  • the method desribed herein anticipates a wide variety of variations in the basic theme of implementation, but can be generalized as a method for detecting a wet shoe in a wellbore casing, the method operating in conjunction with an apparatus integrated into a toe end of the well casing, the apparatus a time delay injection valve with a seating surface built into the valve; the seating surface is configured to seat a restriction plug element; whereby, when a leak is detected in the well casing during a casing integrity test, a restriction plug element is dropped to seat in the conforming seating surface to determine if the leak is due to the wet shoe; wherein said method comprises the steps of:
  • the method described herein anticipates a wide variety of variations in the basic theme of implementation, but can be generalized as a fracturing method for pumping fracturing fluid into a subterranean formation through a controlled time delay apparatus, the controlled time delay apparatus comprising: a housing with openings, a piston, a restrictor, an actuating device and a high pressure chamber with a hydraulic fluid; the stacked delay restrictor is configured to be in pressure communication with the high pressure chamber; a rate of travel of the piston is restrained by a passage of the hydraulic fluid from the high pressure chamber into a low pressure chamber through the stacked delay restrictor; wherein the fracturing method comprises the steps of:
  • staged time delay system for removal of debris in a wellbore casing
  • the staged time delay system comprising a first tool and a second tool
  • the first tool is conveyed with the wellbore casing; wherein when pressurized fluid is injected into the wellbore casing at a maximum pressure, a first injection point in the first tool is opened; the first injection point collects debris from the wellbore casing for a predetermined time; and a second injection point in the second tool is opened after the predetermined time; the second injection point is configured to enable downhole operations after the debris is collected in the first tool leaving the second injection point free of the debris.
  • staged injection method for removal of debris in a wellbore casing, the method operating in conjunction with a staged time delay system, the staged time delay system comprising a first tool and a second tool; wherein the staged injection method comprises the steps of:
  • a sliding sleeve valve for use in a wellbore casing comprising a mandrel with a first threaded end and a second threaded end; the mandrel manufactured from one integral piece such that the mandrel carries a torque rating of the wellbore casing when the mandrel is threaded to ends of the wellbore casing.
  • the method described herein anticipates a wide variety of variations in the basic theme of implementation, but can be generalized as a method of manufacturing a sliding sleeve valve for use in a wellbore casing; the sliding sleeve valve comprising a mandrel with a first threaded end and a second threaded end; the mandrel manufactured from one integral piece such that the mandrel carries a torque rating of the wellbore casing when mandrel is threaded to the wellbore casing; wherein the method comprises the steps of:
  • An apparatus and method for providing a time delay in injection of pressured fluid into a geologic formation has been disclosed.
  • a toe valve activated by fluid pressure that opens ports after a predetermined time interval to allow fluid to pass from a well casing to a formation.
  • the controlled time delay enables casing integrity testing before fluid is passed through the ports.
  • This time delay also allows multiple valves to be used in the same well casing and provide a focused jetting action to better penetrate a concrete casing lining.

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Claims (9)

  1. Testverfahren zum Prüfen einer Unversehrtheit einer Bohrlochhülle mit einer Zeitverzögerungsvorrichtung, wobei die Zeitverzögerungsvorrichtung umfasst:
    ein Gehäuse (29, 51) mit Öffnungen (25, 26, 27), einen Kolben (5, 904, 1001) mit gestuftem Durchmesser, einen Durchflussbegrenzer (22, 902), eine Betätigungsvorrichtung (23, 52) und eine Hochdruckkammer (32, 903) mit einem Hydraulikfluid;
    wobei der Durchflussbegrenzer (22, 902) eingerichtet ist, um mit der Hochdruckkammer (32, 903) in Druckkommunikation zu stehen;
    wobei eine Fortbewegungsrate des Kolbens (5, 904, 1001) mit gestuftem Durchmesser von einem Durchgang des Hydraulikfluids von der Hochdruckkammer in eine Niederdruckkammer (34) durch den Durchflussbegrenzer (22, 902) begrenzt ist;
    wobei der Kolben mit gestuftem Durchmesser sich auf eine Betätigung durch die Betätigungsvorrichtung hin für einen Betätigungszeitraum fortbewegt, wobei nach Ablauf des Betätigungszeitraums die Fortbewegung des Kolbens mit gestuftem Durchmesser ein Öffnen der Öffnungen (25, 26, 27) ermöglicht, so dass Fluid für ein Anschlussöffnungszeitintervall durch die Öffnungen strömt;
    wobei das Testverfahren die folgenden Schritte umfasst:
    (1) Installieren der Bohrlochhülle in einem Bohrloch zusammen mit der Zeitverzögerungsvorrichtung;
    (2) Injizieren des Fluids, um den Druck auf etwa 80% eines maximalen Hüllendrucks zu erhöhen;
    (3) Testen der Unversehrtheit der Bohrlochhülle;
    (4) Erhöhen des Drucks des Fluids, so dass der Druck einen Nenndruck der Betätigungsvorrichtung überschreitet;
    (5) Erhöhen des Drucks des Fluids auf etwa 100 % des maximalen Hüllendrucks, was es dem Kolben mit gestuftem Durchmesser erlaubt, sich für den Betätigungszeitraum fortzubewegen;
    (6) Testen der Unversehrtheit der Bohrlochhülle für den Betätigungszeitraum; und
    (7) Ermöglichen, dass sich der Kolben mit gestuftem Durchmesser fortbewegt, um die Öffnungen für das Anschlussöffnungszeitintervall zu öffnen, so dass das Fluid in die unterirdische Formation hineinströmt.
  2. Testverfahren nach Anspruch 1, wobei der Durchflussbegrenzer (22, 902) eine Kartusche ist, die eine Vielzahl von Verzögerungselementen umfasst, die als eine Reihenkette verbunden sind.
  3. Testverfahren nach Anspruch 1 oder Anspruch 2, wobei die Durchflussbegrenzer (22, 902) eine Kartusche ist, die eine Vielzahl von Verzögerungselementen umfasst, die in einer Kombination von Reihenkette und einer Parallelkette verbunden sind.
  4. Testverfahren nach einem der vorstehenden Ansprüche, wobei der Betätigungszeitraum in einem Bereich von mehr als 60 Minuten bis weniger als 2 Wochen liegt.
  5. Testverfahren nach einem der vorstehenden Ansprüche, wobei der Betätigungszeitraum nahezu 0 Sekunden beträgt, so dass sich die Öffnungen sofort öffnen.
  6. Testverfahren nach einem der vorstehenden Ansprüche, wobei das Anschlussöffnungszeitintervall nahezu 0 Sekunden beträgt.
  7. Testverfahren nach einem der vorstehenden Ansprüche, wobei der Vorrichtung ein Innendurchmesser und einem Außendurchmesser zugeordnet ist; wobei das Verhältnis von Innendurchmesser zu Außendurchmesser in einem Bereich von 0,4 bis 0,9 liegt.
  8. Testverfahren nach einem der vorstehenden Ansprüche, wobei der Vorrichtung ein innerer Werkzeugdurchmesser zugeordnet ist und der Bohrlochhülle ein Innenhüllendurchmesserverhältnis zugeordnet ist; wobei das Verhältnis von innerem Werkzeugdurchmesser zu äußerem Hüllendurchmesser in einem Bereich von 0,4 bis 1,1 liegt.
  9. Testverfahren nach einem der vorstehenden Ansprüche, wobei die Betätigungsvorrichtung eine entgegengesetzt wirkende Berstscheibe ist.
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US14/840,473 US9650866B2 (en) 2013-03-07 2015-08-31 Hydraulic delay toe valve system and method
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CN106481309B (zh) 2021-05-07
CA2939553A1 (en) 2017-02-28
EP3138993A2 (de) 2017-03-08
EP3138993B1 (de) 2021-01-20
CA2939553C (en) 2023-10-03
EP3219906A1 (de) 2017-09-20
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