Patent Publication Number: US-2015060081-A1

Title: Capping stack for use with a subsea well

Description:
CROSS-REFERENCE TO RELATED APPLICATIONS 
     Not applicable. 
     STATEMENT REGARDING FEDERALLY SPONSORED RESEARCH OR DEVELOPMENT 
     Not applicable. 
     NAMES OF THE PARTIES TO A JOINT RESEARCH AGREEMENT 
     Not applicable. 
     INCORPORATION-BY-REFERENCE OF MATERIALS SUBMITTED ON A COMPACT DISC 
     Not applicable. 
     BACKGROUND OF THE INVENTION 
     1. Field of the Invention 
     The present invention relates to blowout preventer systems for use with subsea wells. More particularly, the present invention relates to capping stacks as used in association with the wellhead or the blowout preventer. More particularly, the present invention relates to capping stacks having a plurality of flow passageways formed therein so as to allow the fluid from the subsea well to pass upwardly therethrough and therefrom. 
     2. Description of Related Art Including Information Disclosed Under 37 CFR 1.97 and 37 CFR 1.98. 
     As the worldwide demand for hydrocarbon fuel has increased, and known onshore reserves have not kept up with the demand, there has been increasing activity in offshore oil exploration and production. Reserves of oil known to exist in the offshore areas have steadily increased and an increasing percentage of world production is from these offshore areas. The offshore environment has presented numerous new challenges to the oil drilling industry which have been steadily overcome to allow efficient drilling and production in these areas, although the costs have been considerably higher than those of onshore operations. 
     Not only has the offshore environment made production more difficult to accomplish, it has also generally increased the risk of environmental damage in the event of a well blowout or other uncontrolled loss of hydrocarbons into the sea. As a result, known safety equipment, such as blowout preventers which have been used successfully in onshore operations, have been used in offshore operations also. In spite of safety precautions, blowouts of offshore oil wells are known to occur and will occur in the future. 
     Subsea drilling operations may experience a blowout, which is an uncontrolled flow of formation fluids into the drilling well. These blowouts are dangerous and costly, and can cause loss of life, pollution, damage to drilling equipment, and loss of well production. To prevent blowouts, blowout prevention equipment is required. This blowout prevention equipment typically includes a series of equipment capable of safely isolating and controlling the formation pressures and fluids at the drilling site. BOP functions include opening and closing hydraulically-operated pipe rams, annular seals, shear rams designed to cut the pipe, a series of remote-operated valves to allow control the flow of drilling fluids, and well re-entry equipment. In addition, process and condition monitoring devices complete the BOP system. The drilling industry refers to the BOP system as the BOP stack. 
     The well and the BOP connect the surface drilling vessel to a marine riser pipe, which carries formation fluids (e.g., oil, etc.) to the surface and circulates drilling fluids. The marine riser pipe connects to the BOP through the Lower Main Riser Package (LMRP) which contains a device to connect to the BOP, an annular seal for well control, and flow control devices to supply hydraulic fluids for the operation of the BOP. The LMRP and the BOP are commonly referred to, collectively, as simply the BOP. Many BOP functions are hydraulically controlled, with piping attached to the riser supplying hydraulic fluids and other well control fluids. Typically, a central control unit allows an operator to monitor and control the BOP functions from the surface. The central control unit includes a hydraulic control system for controlling the various BOP functions, each of which has various flow control components upstream of it. 
     While many of the techniques used in onshore operations can be applied in the offshore environment, they often prove to be less effective and require a much longer time period for implementation. For example, while relief wells can drilled to intercept the blowout well, a great amount of time may be required in the drilling operation. In drilling the relief wells, platforms or other drilling support decks must be located and transported to the blowout site before drilling operations can begin. Due to the rugged offshore environment, more time is required to drill the relief wells than would be required in onshore operations. As a result of all of these difficulties, many months can pass between the occurrence of an offshore oil well blowout and the successful final capping of the blown-out well. In the intervening time, large quantities of oil and gas can escape into the ocean with serious environmental impact. 
     While a portion of the hydrocarbons lost from a subsea well blowout may be trapped and skimmed by various containment booms and oil skimmer ships, substantial quantities of hydrocarbons can still escape such containment equipment. It can be seen that once the hydrocarbons are allowed to reach the ocean, surface wave action tends to disburse the lighter hydrocarbons which may mix with water or evaporate into the air. The gaseous hydrocarbons, of course, tend to escape into the atmosphere. The heavier ends of the crude oil often form into globules or tar balls which may flow at, or just below, the water&#39;s surface so as to make it difficult to contain or to skim up. 
     In the past, various patents and patent publications have issued relating to systems for the containment of oil spills and blowouts. For example, U.S. Pat. No. 4,324,505, issued on Apr. 13, 1982 to D. S. Hammett, discloses a subsea blowout containment method and apparatus. This blowout containment apparatus comprises an inverted funnel adapted for positioning over a wellhead to receive fluids from the well and direct them into a conduit extending from the funnel to surface support and processing equipment. The funnel and conduit are supported from the sea&#39;s surface, preferably by a vessel such as a barge. The barge carries the equipment to receive the full flow of fluids from the well, to process the fluids, and to conduct the liquids to a nearby tanker where the recovered liquid hydrocarbons may be stored. 
     U.S. Pat. No. 4,405,258, issued on Sep. 20, 1983 to O&#39;Rourke et al., describes a method for containing oil and/or gas within a blow-out cover dome. This method includes the steps of deploying a containment dome in shallow water near the location of the seabed where the containment dome is to be located. The containment dome has an upper expanded dome-like fluid impervious membrane, a fluid impervious hollow peripheral ring attached to the periphery of the membrane to provide a depending bag-like container, and discrete water drainage means within the bag-like container for connection to pump conduit means therefrom. Wet sand from the seabed is then pumped into the bag-like container. Water is then drained from the wet sand through the water drainage means so as to provide a body of drained sand disposed within the bag-like container and providing a hollow peripheral ring as a hollow peripheral torus acting as a self-supporting structure and as an anchor for the dome-like structural unit. The dome is then charged with a buoyant amount of air and the buoyed dome is floated out to the site where the dome is to be deployed. It is then submerged by controllably releasing the air while substantially simultaneously filling the dome with water, thereby sinking the dome until the lighter-than-water fluid is captured within the dome. 
     U.S. Pat. No. 4,828,024, issued on May 9, 1989 to J. R. Roche, describes a diverter system and blowout preventer. The system comprises a blowout preventer attached above a spool having a hydraulically-driven sleeve/piston. An outlet flow passage exists in the spool. This outlet flow passage can be connected to a vent line. The outlet flow passage is closed off by the sleeve wall when the spool piston is at rest. Hydraulic ports are connected above and below the blowout preventer annular piston and above and below the spool annular piston. The ports below the blowout preventer piston and above the spool piston are in fluid communication with each other. A hydraulic circuit is provided having two valves between a source of pressurized hydraulic fluid and a drain. 
     U.S. Pat. No. 5,984,012, issued on Nov. 16, 1999 to Wactor et al., provides an emergency recovery system for use in a subsea environment. This emergency recovery system has a casing that is open at each end with a shackle connected to one end of the casing with the opposite end of the shackle designed for connection to appropriate points on the main stack and lower marine riser package in any orientation. A flexible sling with a closed loop formed at each end is used with one of the closed loops releasably connected to the shackle and the end of the casing. The other end of the sling has a flotation member attached to the sling adjacent the closed loop. The sling is fan folded as it is lowered into the casing. The flotation member is shaped to fit inside the other end of the casing with the closed end loop of the sling protruding from the casing. The flotation member is constructed of synthetic foam and is sized to provide sufficient buoyancy to fully extend the sling when the release ring is released by a remotely operated vehicle in a subsea environment. 
     U.S. Pat. No. 7,165,619, issued on Jan. 23, 2007 to Fox et al., teaches a subsea intervention system that includes a BOP module and CT module. A tool positioning system is used for positioning a selected subsea tool stored within a rack with a tool axis in line with the BOP axis, while a marinized coiled string injector is moved by positioning system to an inactive position. Power to the subsea electric motors is supplied by an electrical line umbilical extending from the surface for powering the pumps. An injector is provided that includes a pressure compensator roller bearing and a pressure-compensated drive system case. 
     U.S. Pat. No. 7,597,811, issued on Oct. 6, 2009 to D. Usher, provides a method and apparatus for subsurface oil recovery using a submersible unit. The submersible vehicle is positioned above the bed of a diver supported on a platform above the pollutant. A wand at one end of a pipe evacuated by a centrifugal pump is manipulated to draw the pollutant to the surface for treatment or disposal. 
     U.S. Pat. No. 7,921,917, issued on Apr. 12, 2011 to Kotrla et al., shows a multi-deployable subsea stack system. This subsea stack system includes a lower marine riser package, a blowout preventer stack with a first ram blowout preventer, and an additional blowout preventer package releasably coupled to the blowout preventer stack and comprising a second ram blowout preventer. The subsea blowout preventer stack assembly can be deployed by coupling a drilling riser to the lower marine riser package that is releasably connected to the blowout preventer stack. The lower marine riser package and blowout preventer stack are then attached to a subsea wellhead and then landed on the additional blowout preventer package that is coupled to the subsea wellhead. 
     U.S. Patent Publication No. 2009/0095464, published on Apr. 16, 2009 to McGrath et al., provides a system and method for providing additional blowout preventer control redundancy. This system has backup or alternate fluid flow routes around malfunctioning BOP control components using a remotely-installed removable hydraulic hose connection. The backup fluid flow route sends pressure-regulated hydraulic fluid to a BOP operation via an isolation valve rigidly attached to the BOP, then to a hose connected to an intervention panel on the BOP, and finally through a valve that isolates the primary flow route and establishes a secondary flow route to allow continued operation. 
     U.S. Patent Publication No. 2009/0260829, published on Oct. 22, 2009 to D. J. Mathis, provides a subsea tree safety control system that limits the probability of failure on demand of a subsea test tree. A safety shut-in system is provided for actuating a safety valve of the subsea test tree. The safety shut-in system includes a surface control station positioned above a water surface connected via an umbilical to a subsea control system positioned below the water surface so as to actuate the safety valve. 
     U.S. patent application Ser. No. 13/160,032, filed on Jun. 14, 2011 to the present assignee, discloses a diverter system for a subsea well. This diverter system is commonly known as a “capping stack”. This diverter system includes a body having a flow passageway extending therethrough, a ram affixed to the body and extending in transverse relationship to the flow passageway, at least one channel in fluid communication with the flow passageway so as to allow fluid in the flow passageway to pass outwardly of the body, and at least one flowline in valved communication with the flow passageway of the body so as to selectively allow a fluid to be introduced into the flow passageway. The body has an inlet end and an outlet end. The inlet end is suitable for application to an outlet of a blowout preventer. The ram is actuatable so as to change a flow rate of fluid passing through the flow passageway. The channel includes a first channel in valved communication with the flow passageway and a second channel in valved communication with the flow passageway. Each of these channels extend in transverse relationship to the flow passageway so as to pass fluid from the flow passageway to a location away from the body. 
     The product that is sold by Trendsetter Engineering, Inc. that is the subject of U.S. application Ser. No. 13/160,032 has been a highly successful product for the company. This product is relatively heavy and has a weight in the order of between 100 to 150 tons. Since the flow diverter sends the fluid flow in perpendicular relationship to the flow from the blowout preventer, there is a possibility of erosion to the internal components of the capping stack when the fluid flows at very high rates. The single centralized bore is limited by the available valve/ram sizes. In this product, the central bore extends entirely through the body of the capping stack. As such, in order to install the capping stack, the central bore remains open during installation. As such, the fluid flowing from the blowout preventer will pass freely through the central bore of the capping stack during installation. Once the product is installed on the blowout preventer, the central bore is closed by rams (in the nature of a blowout preventer) so as to stop the flow through the central bore of the capping stack. At that time, the channels can be either closed so as to retain the flow of fluids in the well or open so as to allow the fluids to be removed from the capping stack. 
     After extended use of the present invention, it was found that it would be desirable to significantly reduce the weight of the capping stack. The weight of the capping stack requires that the capping stack be assembled on location. Very few airplanes have the capacity to carry the entire assembled capping stack to the desired location. The relatively large size of the this capping stack can be somewhat difficult to maneuver between the risers of tension leg platforms or spar platforms. Additionally, although the capping stack is within the limits of cranes associated with offshore platforms, it does require the maximum capacity of such equipment. Since the capping stack is required to be assembled at the location, additional testing is required once the capping stack is reassembled. Although the capping stack is very heavy, the actual weight of the capping stack is of no particular value for the closing or control of the well. 
     It is an object of the present invention to provide a capping stack of relatively small size and of minimal weight. 
     It is another object of the present invention to provide a capping stack having bores and flowlines which minimize the effects of erosion when fluids flow through such bores and flowlines at high flow rates. 
     It is another object of the present invention to provide a capping stack that has a minimal number of components. 
     It is another object of the present invention to provide a capping stack that does not require reassembly and retesting. 
     It is another object of the present invention to provide a capping stack which avoids the use of rams for the closing of the flow passageway. 
     It is another object of the present invention to provide a capping stack that provides the ability to capture fluids from the subsea well. 
     It is a further object of the present invention to provide a capping stack which allows the weight of the capping stack to be actively used to create pressure against the flow of fluid from the well. 
     It is still another object of the present invention to provide a capping stack that can be easily maneuvered between the risers of tension leg platforms or spar platforms. 
     It is still a further object of the present invention to provide a capping stack that is relative easy to handle on boats and offshore platforms and easily within the limits of existing equipment. 
     It is still a further object of the present invention to provide an assembled capping stack that can be shipped as air freight, on demand, to a desired location. 
     It is still a further object of the present invention to provide a capping stack that minimizes the risk of damage to a wellhead. 
     These and other objects and advantages of the present invention will become apparent from a reading of the attached specification and appended claims. 
     BRIEF SUMMARY OF THE INVENTION 
     The present invention is a capping stack for use with a subsea well. The capping stack includes a body with a flow passageway extending therethrough. The flow passageway has an inlet suitable for connection to a fluid passageway of a blowout preventer or to a wellhead of subsea well. The body has a first bore having one end opening to an outlet end of the flow passageway. The first bore extends upwardly from the flow passageway. The body of the second bore has one end opening to the outlet end of the flow passageway. The second bore also extends upwardly from the flow passageway. A first flowline is affixed to the first bore and extends upwardly therefrom. A second flowline is affixed to the second bore and extends upwardly therefrom. A first valve is cooperative with the first flowline so as to be movable between an open position and a closed position. The open position is suitable allowing fluids from the subsea well to flow through the first flowline. The closed position is suitable for blocking fluids from passing outwardly of the first flowline. A second valve is cooperative the second flowline so as to be movable between an open position and a closed position. The open position of the second valve allows fluid from the subsea well to flow through the second flowline. The closed position of the second valve blocks fluid from passing outwardly of the second flowline. 
     In the present invention, a connector is affixed to a lower end of the body. The connector is suitable for connecting the body to either the blowout preventer or the wellhead. A frame is connected to the body and extends upwardly therefrom. 
     The first bore diverges away from the second bore in a direction away from the outlet end of the flow passageway. The first bore extends an angle of 60° or less to vertical. The second bore extends at an angle of 60° or less to vertical. One end of the first bore is in spaced relation to the end of the second bore at the outlet end of the flow passageway. Each of the first and second bores has a cross-sectional area less than a cross-sectional area of the flow passageway. 
     In the present invention, there can be a third bore having one end opening to the outlet end of the flow passageway. The third bore extends upwardly from the flow passageway. A third flowline is affixed to the third bore and extends upwardly therefrom. A third valve is cooperative with the third flowline so as to be movable between an open position and a closed position. The open position of the third valve allows fluids from the subsea well to flow through the third flowline. The closed position of the third valve blocks fluids from passing outwardly of the third flowline. The third bore diverges away from the first and second bores in a direction away from the outlet end of the flow passageway. 
     In the present invention, the first valve can include a pair of valves that are cooperative with the first flowline. The pair of valves are in spaced relationship to each other. The second valve can also be a pair of valves that are cooperative with the second flowline. The pair of valves of the second valve are in spaced relationship to each other. 
     Each of the first and second flowlines includes a first portion having a first end and a second end. The first end connected to the respective bore. The first portion extends at an acute angle to vertical away from the respective bore. Each of the first and second flowlines also includes a second portion extending from the second end of the first portion and extending vertically upwardly therefrom. Each of the first and second flowlines has connecting portion at an upper end thereof. This connecting portion is suitable for connection to a conduit so as to allow fluids from the subsea well to flow therefrom. 
     A lifting mechanism can be affixed to an upper portion of the frame in a location generally centrally of the frame. This lifting mechanism is suitable for allowing a hoist or a crane to lift the capping stack and to lower the capping stack, as desired. 
     The foregoing Section is intended to describe, with particularity, the preferred embodiment of the present invention. It is understood that modifications to this preferred embodiment can be made within the scope of the present invention. As such, this Section is not intended, in any way, to be limiting of the broad scope of the present invention. The present invention should only be limited by the following claims and their legal equivalents. 
    
    
     
       BRIEF DESCRIPTION OF THE SEVERAL VIEWS OF THE DRAWINGS 
         FIG. 1  is a perspective view of the capping stack of the present invention. 
         FIG. 2  is a cross-sectional view showing the capping stack of the present invention. 
         FIG. 3  is an exploded view showing the relationship of the capping stack of the present invention to a blowout preventer. 
         FIG. 4  is a perspective view showing an alternative embodiment of the capping stack of the present invention. 
         FIG. 5  is an upper perspective view of a further alternative embodiment of the capping stack of the present invention. 
         FIG. 6  is an internal perspective view showing the arrangement of bores formed within the body of the capping stack of the present invention. 
     
    
    
     DETAILED DESCRIPTION OF THE INVENTION 
     Referring to  FIG. 1 , there is shown the capping stack  10  in accordance with the teachings of the present invention. The capping stack  10  includes a body  12  having a connector  14  located at a bottom end thereof. The body  12  has a generally cylindrical configuration. The connector  14  is suitable for connection to either a subsea wellhead or an upper end of a blowout preventer. A frame  16  is affixed to the body  12  at an upper end of the body  12 . The frame  16  supports a first flowline  18  and a second flowline  20  thereon. Each of the first flowline  18  and the second flowline  20  extends vertically upwardly. A third flowline  22  can also be supported by the frame  16 . As will be described hereinafter, there is a first valve associated with the flowline  18 , a second valve associated with the second flowline  20  and a third valve associated with the third flowline  22 . As can be seen in  FIG. 1 , the frame  16  supports a panel  24 . The panel  24  supports a first actuator  26  for control of the valve associated with the first flowline  18 , a second actuator  28  that controls the operation of the valve associated with the second flowline  20  and a third actuator  30  that controls the operation of the valve associated with the third flowline  22 . A suitable lifting mechanism, such as padeye  32 , is positioned on an upper portion of the frame  16  so as to allow suitable cranes or hoists to lift and lower the capping stack  10 , as desired. 
       FIG. 2  shows a cross-sectional view of the capping stack  10  of the present invention. The capping stack  10  includes the body  12  having the connector  14  at a lower end thereof. The body  12  has a flow passageway  34  extending vertically therethrough. Flow passageway  34  has a relatively large diameter. The flow passageway  34  has an inlet end  36  and an outlet end  38 . As can be seen in  FIG. 2 , the body  12  includes a lower body portion  40  that is bolted to an upper body portion  42 . 
     The upper body portion  42  has a first bore  44  and a second bore  46  extends therethrough. Although the term “bore” is used, it is understood that, within the concept of the present invention, similar items, such as pipe, conduits, hoses, or other devices, could also be considered as “bores”. 
     In  FIG. 3 , it can be seen that the first bore  44  has one end opening to the outlet end  38  of the flow passageway  34 . The second bore  46  also has an end opening to the outlet end  38  of the flow passageway  34 . Each of the bores  44  and  46  diverge away from each other in a direction away from the outlet end  38  of the flow passageway  34 . The ends of the bores  44  and  46  are in spaced relationship to each other at the outlet end  38  of the flow passageway  34 . Within the concept of the present invention, each of the bores  44  and  46  extends upwardly at an acute angle of less than 60° to vertical. In the preferred embodiment of the present invention, the bores  44  and  46  should extend at 45° to vertical. 
     Through the arrangement of the bores  44  and  46 , as shown in  FIG. 2 , the fluid passing through the flow passageway  34  is diverted into the bores  44  and  46 . Since the bores  44  and  46  extend at an acute angle to vertical, rather than transverse to vertical, there is less possibility of erosion caused by particles entrained within a fluid passing at a high flow rate through the flow passageway  34  and into the bores  44  and  46 . Each of the bores  44  and  46  has a cross-sectional area that is less than the cross-sectional area of the flow passageway  34 . As such, the flow passageway  34  is diverted into smaller bores. 
     The first bore  44  is connected to the first flowline  18 . A first valve  48  is cooperative with the first flowline  18  so as to control the flow of fluid into and through the first flowline  18 . The first valve  48  is a gate valve. A suitable ROV can be utilized so as to open and close the valve  48 . In the closed position, the valve  48  blocks the flow of fluid from the bore  44  into the flowline  18 . In the open position, the valve  48  allows for the flow of fluid from the bore  44  through the flowline  18 . 
     The second bore  46  is connected to the second flowline  20 . A second valve  50  is cooperative with the second flowline  20  so as to control the flow of fluid from the bore  46  into and through the second flowline  20 . In the open position, the valve  50  allows for the flow of fluid from the bore  46  through the second flowline  20 . In the closed position, the valve  50  will block the flow of fluid from the bore  46  into the second flowline  20 . 
     The first flowline  18  has a first portion  52  that has an end connected to the first bore  44 . The first portion  52  extends at the same acute angle that the first bore  44  extends and is axially aligned with the first bore  44 . The opposite end of the first portion  52  is connected to a second portion  54 . The second portion  54  extends vertically upwardly. The first flowline  18  includes an outlet  56  at an upper end thereof. Outlet  56  is located at a convenient location for the attachment of a conduit, or other piping, such that fluids passing through the first flowline  18  can be diverted to another location, such as surface location. Through this angled relationship, the flow of fluid through the first portion  52  and the second portion  54  is gradually transitioned rather than having any sharp angles (which could cause erosion). It can be seen that there is connection portion  58  located adjacent to the end  56 . Connection portion  58  allows the first flowline  18  to be connected to the corresponding conduit. 
     The second flowline  20  also includes a first portion  60  and second portion  62  that extend in similar manner as portions  52  and  54  of the first flowline  18 . The valves  48  and  50  are respectively connected to the first portion  52  and  60  of the respective flowlines  18  and  20 . The second flowline  20  also includes a connection portion  64  located adjacent to the end  66 . 
       FIG. 2  further shows the frame  16  as supporting the flowlines  18  and  20  thereon. The frame  16  provides a strong structure for the support of the various components of the present invention. Additionally, another type of lifting mechanism  68  is secured to the frame  16  so as to facilitate the ability to lift and lower capping stack  10 , as desired. 
     With reference to  FIG. 2 , it can be seen that valves  48  and  50  are utilized in the capping stack  10 . As such, the capping stack  10  avoids the use of complicated ram mechanisms associated with other capping stacks. The valves  48  and  50  are readily available for use. As such, the constructural complexity associated with installing the ram mechanisms on the capping stack  10  is avoided. Since each of the bores  44  and  46  and the flowlines  18  and  20  are of a relatively minimal diameter, the requisite flow of fluid through the interior of the capping stack  10  can be achieved. As such, when it is desired to place the capping stack  10  upon a blowout preventer or on a wellhead, the valves  48  and  50  can be opened so as to allow for the free flow of fluid therethrough. As such, if fluids are being released by the blowout preventer, the fluid will enter the flow passageway  34 , pass through the bores  44  and  46 , and outwardly through the flowlines  18  and  20 . Since there is small area of contact between the ends of the bores  44  and  46  at the outlet end  38  of the flow passageway  34 , a certain amount of resistance will occur when attempting to the lower the capping stack  10  onto the wellhead or the blowout preventer. However, the present invention actually uses the weight of the capping stack  10  so as to overcome any resistance that may be created by this small surface. As such, the present invention effectively utilizes the weight of the capping stack in the capping of the blowout preventer. 
     Once the capping stack  10  is installed, the valves  48  and  50  can be closed so as to close off the blowout preventer or the wellhead. When proper pressures are realized, and when suitable conduits are connected to the connection portions  58  and  64  of the capping stack  10 , the valves  48  and  50  can be respectively opened so as to allow for the release of fluids therethrough. As such, these fluids can be effectively recovered at another location, such as a surface location. 
       FIG. 3  shows the installation of the capping stack  10  onto a blowout preventer  70 . It can be seen that the blowout preventer  70  is secured to a wellhead  72  located at a subsea floor  74 . In normal fashion, the blowout preventer  70  is properly secured to the wellhead  72  and extends upwardly therefrom. There is a mandrel  76  located at the upper end of the blowout preventer  70 . 
     The capping stack  10  is secured by placing the connector  14  over the mandrel  76 . Suitable conventional locking mechanisms can be provided whereby the body  12  of the capping stack  10  is secured to the mandrel  76  in fluid-tight relationship. As such, the body  12  can be suitably locked to the mandrel  76  so as to establish a fluid flow relationship between the fluid passing through the mandrel  76  of the blowout preventer  70  and the flow passageway  34  of the body  12 . 
       FIG. 3  shows the capping stack  10  as having three bores, and showing in particular, a third bore  78 . Third bore  78  can have a third valve  80  positioned thereon. Additionally, the third flowline  22  will extend from the third bore  78 . As such,  FIG. 3  shows a total of three bores that are utilized so as to divert the fluid flow from the blowout preventer  70 . 
     With reference to  FIG. 3 , there are certain circumstances where the blowout preventer  70  may be slightly tilted at an angle to vertical. This could occur during a subsea event or if the blowout preventer  70  is improperly installed. In past circumstances, if the capping stack  10  were too heavy, then it could exert forces which would tend to further deflect the blowout preventer  70 . The lower weight of the capping stack  10  is less likely to create such forces and will operate so as to maintain the blowout preventer  70  in its existing orientation. 
     In certain circumstances, the capping stack  10  could be applied to the wellhead  72  rather than the blowout preventer. Under this circumstance, the connector  14  of the body  12  is simply placed over the wellhead  72  such that the capping stack  10  is joined directly to the wellhead  72  so as to control for the release of fluids from the well. 
       FIG. 4  shows another embodiment of the capping stack  100  of the present invention. Capping stack  100  includes a body  102  and flowlines  104 ,  106  and  108  extending upwardly therefrom. Importantly, in  FIG. 4 , it can be seen that the first flowline  104  includes a first valve actuator  106  provided on the frame  108 . A second valve actuator  110  is also supported by the frame  108 . 
     The first flowline  104  will include a first valve associated with the actuator  106  and a second valve  112  located at an upper end thereof. As such, these valves will be in spaced relationship to each other. It is found that, under certain circumstances, customers desire to have redundancy in the control of fluids from the subsea well. As such, applying two valves to each of the flowlines  104  and  106  can accomplish this purpose. Flowline  104  will also include a transition section  116  so as to allow for a suitable connector to be applied to flange  118  so as to allow for the release of fluids from the first flowline  104 . The second flowline  106  also includes a valve associated with the actuator  104  located on the first portion of the transition member  106  adjacent to the bores and the body  102  and a second valve  120  positioned in spaced relationship to the first valve. Another diverter member  122  is located at the upper end of the second flowline  106  so as to allow for the diverter member  122  to transmit fluids outwardly of the flange portion  124 . 
     The capping stack  100  includes various lifting bars  126 ,  128  and  130  extending upwardly therefrom. Additionally, a padeye  132  can be directly affixed to the frame  108 . As such, these lifting mechanisms facilitate the ability to lift and lower the capping stack  100 . 
       FIG. 5  shows a further embodiment of the capping stack  200  of the present invention. Capping stack  200  includes a body  202  having a connector  204  located at a lower end thereof. The capping stack  200  includes four flowlines  206 ,  208 ,  210  and  212 . The frame  214  supports each of the flowlines  206 ,  208 ,  210  and  212  such that they extend upwardly vertically.  FIG. 5  shows a bucket  216  for the control of the valve associated with the flowline  210  and a bucket  218  for the control of the valve associated with the flowline  220 . Suitable additional buckets (not shown) can be utilized so that an ROV can effectively control the operation of the flowlines  206  and  208 . The body  202  will include a total of four bores which extend so as to be connected to each of the flowlines  206 ,  208 ,  210  and  212  in the manner described in the previous embodiments. As such, the capping stack  200  allows for the diversion of flow along four separate pathways. The capping stack  200  is adaptable to enhance the capacity to remove greater amounts of fluid from the well or for the ability to reduce the diameter of each of the flowlines  206 ,  208 ,  210  and  212 , along with the valves associated therewith. 
       FIG. 6  shows a detailed view of the upper body which includes the bore spool  222  of the capping stack  200 . As can be seen, the bore spool  222  includes a first bore  224 , a second bore  226 , a third bore  228  and a fourth bore  230  extending so as to diverge from one another within the bore spool  222 . The bore spool  222  has a flange  232  that is suitable for attachment to the lower body portion of body  222 . Each of the bores  224 ,  226 ,  228  and  230  has a flange thereon whereby the respective bores can be secured to the respective flowlines  206 ,  208 ,  210  and  212 . Each of the bores  224 ,  226 ,  228  and  230  has a lower end that will open to the outlet end  234  of the flow passageway (such as flow passageway  34  in  FIG. 2 ). In this manner the flow of fluids through the flow passageway  34  is diverted at acute angles to vertical through the respective bores  224 ,  226 ,  228  and  230 . 
     The present invention significantly reduces the size and weight of the capping stack. Since the size is reduced, it is easier to maneuver between the risers of tension leg platforms or spar platforms. Additionally, the relatively small size of the capping stack of the present invention allows the entire capping stack to be positioned within the storage bay of a transport airplane. Since the weight of the capping stack of the present invention is estimated to be between thirty and forty tons, it can be easily transported by conventional air transport planes. As such, the capping stack of the present invention can be stored in one location and delivered to a remote location in a relatively minimal amount of time. As such, the present invention avoids the need to deploy separate capping stacks in the various areas of hydrocarbon production. The relatively small weight of the capping stack allows it to be easily handled on boats or with existing equipment on an offshore platform. 
     The gradual transitions between the flow passageway and the bores and the flowlines reduces the possibility of erosion. If sharp turns of a fluid will occur in a capping stack, then there is the possibility, over time, of the erosion of the internal structures of the capping stack. As such, the gradual transitions provided by the capping stack of the present invention will minimize the risk of erosion caused by the high rates of fluid. 
     The present invention has a smaller number of components than existing capping stacks. As such, the amount of testing is reduced. There is less reassembly and retesting of the capping stack. The capping stack, in view of its small size and weight, can be delivered entirely intact to the desired location. As such, it is not necessary to deliver the capping stack in pieces and then assemble the capping stack at the location. 
     The present invention utilizes valves instead of rams. As such, it is not limited, in any way, by ram availability or ram sizes. It also avoids the complex mechanisms associated with the installation of such rams. 
     The foregoing disclosure and description of the invention is illustrative and explanatory thereof. Various changes in the details of the illustrated construction can be made within the scope of the appended claims without departing from the true spirit of the invention. The present invention should only be limited by the following claims and their legal equivalents.