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TECHNICAL FIELD 
       [0001]    This invention relates to the general subject of providing for the flow of fluids in a subsea environment in which volumes are required to be stored under pressure in bottles as a ready reserve and are needed to be deployed to operate low pressure functions, high pressure functions, and functions which require low pressure at one time and high pressure at another time. 
       CROSS-REFERENCE TO RELATED APPLICATIONS 
       [0002]    Not applicable. 
       STATEMENT REGARDING FEDERALLY SPONSORED RESEARCH OR DEVELOPMENT 
       [0003]    Not applicable 
       REFERENCE TO A “MICROFICHE APPENDIX” 
       [0004]    Not applicable 
       BACKGROUND OF THE INVENTION 
       [0005]    The field of this invention is that of providing fluid power to operate subsea components such as the shear rams of subsea blowout preventers and similar components. These components typically make up what is called a subsea blowout preventer stack and have a high volume requirement to operate an appropriate number of these functions. It can range up to  200  gallons of accumulated capacity necessary to operate various blowout preventers and valves on a subsea blowout preventer stack. In many cases such as with shear rams the pressure required to stroke the shear rams to the point of contacting the pipe to be sheared is relatively low (i.e. 500 p.s.i.) and then the force required to shear the pipe is relatively high (i.e. 5000 p.s.i.). 
         [0006]    This is further complicated by the fact that an accumulator typically pressurizes the fluid by having compressed gas such as nitrogen provide pressure on the fluid. The compressibility of the gas allows a substantial volume of fluid to be pressurized and then discharged under pressure. A disadvantage of this is that as the liquid is discharged from the accumulator, the volume of the gas becomes larger and therefore the pressure of the gas and liquid becomes lower. As the pistons and rams of the blowout preventer move forward and need higher pressure to do their functions, the pressure of the powering fluid becomes lower. This has typically meant that the lowest pressure from the accumulator must exceed the highest operational pressure of the system. The highest pressure of the accumulator to make this work is simply higher. When a higher pressure is provided by the accumulator than is needed, it is simply throttled to reduce the pressure and turn the energy into heat. 
         [0007]    This has been the nature of the operations of subsea accumulators for the past 50 years. There has been a long felt need for more accumulator volume capacity and the only way that those skilled in the art have met the challenge is with larger and higher pressure accumulators. 
       BRIEF SUMMARY OF THE INVENTION 
       [0008]    The object of this invention is to provide an accumulator system which provides a relatively lower pressure at the start of the stroke of an operated device and a relatively higher pressure at the end of the stroke of an operated device. 
         [0009]    A second object of this invention is to provide a system which fully utilizes the stored energy of an accumulator rather than throttling the pressure and discarding the energy as wasted heat. 
         [0010]    A third object of this invention is to provide fluid flow at the pressure which is required by the operated function. 
     
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
         [0011]      FIG. 1  is a view of a deepwater drilling system such as would use this invention. 
           [0012]      FIG. 2  is a partial section of a blowout preventer stack showing conventional operation. 
           [0013]      FIG. 3  is a schematic showing the conventional pressure decline of an accumulator as the fluid is discharged. 
           [0014]      FIG. 4  is a schematic showing the conventional pressure decline of an accumulator as the fluid is discharged with the area below the graphed line cross hatched to illustrate the energy expended. 
           [0015]      FIG. 5  is the schematic of  FIG. 3  with an added line indicating the actual pressure requirement of a function to be operated. 
           [0016]      FIG. 6  is the schematic of  FIG. 5  with the utilized and wasted energy cross hatched. 
           [0017]      FIG. 7  is a partial section of a blowout preventer stack showing pumps and motors arranged according to the method of this invention in a simple form. 
           [0018]      FIG. 8  is a schematic illustrating how much energy can be saved when operating the function illustrated in  FIG. 5 . 
           [0019]      FIG. 9  is a schematic illustrating the pressure requirement of a function such as shearing pipe which has a portion of the stroke actually requiring high pressure. 
           [0020]      FIG. 10  is the schematic of  FIG. 9  with the utilized and wasted energy cross hatched. 
           [0021]      FIG. 11  is a schematic illustrating how much energy can be saved by the present method. 
           [0022]      FIG. 12  is a partial section of a blowout preventer stack showing pumps and motors arranged according to the method of this invention in variable displacement form. 
       
    
    
     DETAILED DESCRIPTION OF THE INVENTION 
       [0023]    Referring now to  FIG. 1 , a view of a complete system for drilling subsea wells  20  is shown in order to illustrate the utility of the present invention. The drilling riser  22  is shown with a central pipe  24 , outside fluid lines  26 , and cables or hoses  28 . 
         [0024]    Below the drilling riser  22  is a flex joint  30 , lower marine riser package  32 , lower blowout preventer stack  34  and wellhead  36  landed on the seafloor  38 . 
         [0025]    Below the wellhead  36 , it can be seen that a hole was drilled for a first casing string  40 , that first casing string  40  was landed and cemented in place, a hole drilled through the first string for a second string, the second string  42  cemented in place, and a hole is being drilled for a third casing string by drill bit  44  on drill string  46 . 
         [0026]    The lower Blowout Preventer stack  34  generally comprises a lower hydraulic connector for connecting to the subsea wellhead system  36 , usually 4 or 5 ram style Blowout Preventers, an annular preventer, and an upper mandrel for connection by the connector on the lower marine riser package  32 , which are not individually shown but are well known in the art. 
         [0027]    Below outside fluid line  26  is a choke and kill (C&amp;K) connector  50  and a pipe  52  which is generally illustrative of a choke or kill line. Pipe  52  goes down to valves  54  and  56  which provide flow to or from the central bore of the blowout preventer stack as may be appropriate from time to time. Typically a kill line will enter the bore of the Blowout Preventers below the lowest ram and has the general function of pumping heavy fluid to the well to overburden the pressure in the bore or to “kill” the pressure. The general implication of this is that the heavier mud cannot be circulated into the well bore, but rather must be forced into the formations. A choke line will typically enter the well bore above the lowest ram and is generally intended to allow circulation in order to circulate heavier mud into the well to regain pressure control of the well. Normal circulation is down the drill string  46 , through the drill bit  44 . 
         [0028]    In normal drilling circulation the mud pumps  60  take drilling mud  62  from tank  64 . The drilling mud will be pumped up a standpipe  66  and down the upper end  68  of the drill string  46 . It will be pumped down the drill string  46 , out the drill bit  44 , and return up the annular area  70  between the outside of the drill string  46  and the bore of the hole being drilled, up the bore of the casing  42 , through the subsea wellhead system  36 , the lower blowout preventer stack  34 , the lower marine riser package  32 , up the drilling riser  22 , out a bell nipple  72  and back into the mud tank  64 . 
         [0029]    During situations in which an abnormally high pressure from the formation has entered the well bore, the thin walled central pipe  24  is typically not able to withstand the pressures involved. Rather than making the wall thickness of the relatively large bore drilling riser thick enough to withstand the pressure, the flow is diverted to a choke line or outside fluid line  26 . It is more economic to have a relatively thick wall in a small pipe to withstand the higher pressures than to have the proportionately thick wall in the larger riser pipe. 
         [0030]    When higher pressures are to be contained, one of the annular or ram Blowout Preventers are closed around the drill pipe and the flow coming up the annular area around the drill pipe is diverted out through choke valve  54  into the pipe  52 . The flow passes up through C&amp;K connector  50 , up pipe  26  which is attached to the outer diameter of the central pipe  24 , through choking means illustrated at  74 , and back into the mud tanks  64 . 
         [0031]    On the opposite side of the drilling riser  22  is shown a cable or hose  28  coming across a sheave  80  from a reel  82  on the vessel  84 . The cable or hose  28  is shown characteristically entering the top of the lower marine riser package. These cables typically carry hydraulic, electrical, multiplex electrical, or fiber optic signals. Typically there are at least two of these systems for redundancy, which are characteristically painted yellow and blue. As the cables or hoses  28  enter the top of the lower marine riser package  32 , they typically enter the top of a control pod to deliver their supply or signals. Hydraulic supply is delivered to a series of accumulators located on the lower marine riser package  32  or the lower Blowout Preventer stack  34  to store hydraulic fluid under pressure until needed. 
         [0032]    Referring now to  FIG. 2 , a partial section of several parts of the conventional state of the art system for drilling subsea wells is shown including a wellhead connector  100 , ram type blowout preventers  102  and  104 , annular blowout preventer  106 , flex joint  30 , and drilling riser central pipe  24 . 
         [0033]    Ram type blowout preventer  104  has pistons  110  and  112  which move rams  114  and  116  into central bore  118 . Fluid flow into line  120  will move the pistons and rams forward to seal off bore  118  with return flow going out line  124 . Fluid flow into line  124  will move the pistons and rams out off bore  118  with return flow going out line  120 . 
         [0034]    Control pod  130  receives electric and communication signals from the surface along line  132  and receives hydraulic supply from line  134 , and exhausts hydraulic fluid to sea along line  136 . Accumulator  140  receives pressurized hydraulic supply from the surface along line  142  and supplies the control pod  130  when appropriate. Electro-hydraulic valve  138  receives hydraulic supply from accumulator  140  and directs the hydraulic supply to open or close the rams of blowout preventer  104   
         [0035]    Referring now to  FIG. 3 , a graph is shown for fluid which might be coming out of an accumulator such as is shown at  140 . For understanding, this graph presumes that the accumulator will go from fully charged to fully discharged when moving one function from open (fully charged) to closed (discharged) as shown by line AB. In reality an accumulator might operate several functions, or several accumulators can be required to operate one function. 
         [0036]    Referring now to  FIG. 4 , the area under line AB is cross hatched. As the energy expended from an accumulator is proportionate to the product of the volume times the pressure, the cross hatched area is generally an indication of the amount of energy of the accumulator. 
         [0037]    Referring now to  FIG. 5 , line CD indicates the actual flow and pressure which could be utilized to close a function. It generally indicates that 900 p.s.i. will close it, but the entire volume of the accumulator is required. 
         [0038]    Referring now to  FIG. 6 , the area below line CD is proportionate to the utilized energy in closing the function and the cross hatched area between lines AB and CD is wasted energy. This energy in excess of the required amount will be burned up in faster than required operations and resultant line flow friction losses. This generally indicates that 25% of the energy was used and 75% of the energy was wasted. 
         [0039]    Referring now to  FIG. 7 , the output of accumulator is not directed to control valve but rather to motor  150 . Motor  150  output torque is directed to drive pumps  152 ,  154 , and  156 , all of which have the same volume displacement for the purpose of this example. As line  134  required 900 p.s.i. in the example of  FIGS. 5 and 6 , line  158  will require 3*900=2700 p.s.i. to drive the motors, which is readily available from the accumulator  140 . Low pressure tank  160  is provided to collect the returns from control valve  138  such that when 3 times as much is drawn from tank  160  by pumps  152 ,  154 , and  156  as is put into tank by motor  150 , standard control fluid will be available. As control valve  138  exhausts into tank  160 , excess flow will be vented to sea through line  162 . 
         [0040]    Referring now to  FIG. 8 , this is shown graphically. On the X scale is can be seen that only ⅓ of the volume of the accumulator was expended, and the Y scale shows that it was expended at 3 times the pressure, for the same cross hatched area below line EF. The wasted energy between lines EF and GH is less than ¼ of the wasted energy as seen in  FIG. 6  to do the same job. Referring now to  FIG. 9 , line JKLMNP indicates a special operation such as a shear ram on a subsea blowout preventer stack in which a higher pressure is actually needed. In this case as the pistons moved from J to K, the same 900 p.s.i. was required as was in the prior figures. When the shearing of the steel pipe was being done, 2900 p.s.i. as shown in line segment LM was required. After the shearing was accomplished, only 900 p.s.i. was required to continue moving to the sealing position as shown line segment NP. 
         [0041]    Referring now to  FIG. 10 , it can be seen that the wasted energy between lines JKLMNP and AB is almost as much as was wasted in  FIG. 6 . 
         [0042]    Referring now to  FIG. 11 , if all the accumulator pressure is expended at the maximum required pressure, we can reduce the required volume by more than 50 percent and substantially reduce the wasted volume as is seen between lines AQ and RS. 
         [0043]    Referring now to  FIG. 12 , the three pumps  152 ,  154 , and  156  of  FIG. 7  are replaced by a single pump  170 . The pump  170  is a variable displacement pump which is horsepower limited. This means that when the combination of pressure and flow rate (a measure of horsepower) exceeds a maximum, the variable flow rate is lowered until the horsepower setting is not exceeded. In the example of  FIGS. 9 and 10 , if the horsepower is set to that calculated by the given flow rate times 2900 p.s.i., the pipe will be sheared as was anticipated in  FIGS. 9 and 10 . At the times when the pipe is not being sheared, the 2900 p.s.i. cannot be achieved in line  134 . As a result the variable displacement pump will change the displacement until the increased flow times 900 p.s.i. will equal the original flow time 2900 p.s.i. In this case the flow will need to be adjusted upwardly by (2900/900=3.22) a factor of 3.22/1. As the same volume is actually required to move the pistons and rams, it means that in the non-shearing portion of the stroke, the volume required from the accumulator will be reduced by a factor of 3.22. 
         [0044]    Referring back to  FIG. 11 , it can be seen that the net required volume from the accumulators can be reduced by more than 50%. This means that the size of the required accumulators can be reduced to accomplish the set of required tasks, or that more capability can be provided by the same accumulators. 
         [0045]    The same benefit can be obtained if the motor is the variable displacement device and the pumps are fixed displacement. The volume output of the pumps is generally inversely proportionate to the required pressure to operate the device to be operated. 
         [0046]    The previous examples have shown how to increase the flow volume from an accumulator to an operated device. Alternately, the flow to the device can be decreased in order to achieve a higher pressure. 
         [0047]    The particular embodiments disclosed above are illustrative only, as the invention may be modified and practiced in different but equivalent manners apparent to those skilled in the art having the benefit of the teachings herein. Furthermore, no limitations are intended to the details of construction or design herein shown, other than as described in the claims below. It is therefore evident that the particular embodiments disclosed above may be altered or modified and all such variations are considered within the scope and spirit of the invention. Accordingly, the protection sought herein is as set forth in the claims below. 
         [0000]    SEQUENCE LISTING: N/A

Summary:
In a subsea system where subsea devices are operated using a pressurized fluid from one or more accumulators, the method of providing flow of pressurized fluid to operate a device which is greater than the flow from an accumulator providing the flow, comprising discharging the accumulator to drive one or more motors, driving one or more pumps by the one or more motors, the one or more pumps having a larger displacement than the one or more motors such that the one or more pump outputs a greater volume of fluid than the motor consumes, and delivering the output of the one or more pumps to operated the subsea device.