Patent Publication Number: US-8109330-B1

Title: Inline choke and angled choke for use with oil field equipment

Description:
FIELD 
     The present embodiments generally relate to an inline choke and an angled choke for use with oil field equipment, such as choke and kill manifolds. 
     BACKGROUND 
     A need exists for an inline choke and an angled choke of modular construction that has modular parts. 
     A need exists for inline and angled chokes that are longer lasting than existing chokes. 
     A need exists for inline and angled chokes that are easy to repair and replace. 
     The present embodiments meet these needs. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
       The detailed description will be better understood in conjunction with the accompanying drawings as follows: 
         FIG. 1  is a cross sectional view of an embodiment of an inline choke. 
         FIG. 2  is a perspective view of the inline choke in  FIG. 1 . 
         FIG. 3  is a cross sectional view of an embodiment of an angled choke. 
         FIG. 4  is a cross sectional view of a choke with a right angle studded connection. 
         FIG. 5  is a perspective view of the choke in  FIG. 4 . 
         FIGS. 6A-6B  depict an embodiment of a connection between a flanged connection and a choke body. 
         FIG. 7  is a cross sectional view of another embodiment of the angled choke having a carbide tip with a counter bore. 
     
    
    
     The present embodiments are detailed below with reference to the listed Figures. 
     DETAILED DESCRIPTION OF THE EMBODIMENTS 
     Before explaining the present apparatus in detail, it is to be understood that the apparatus is not limited to the particular embodiments and that it can be practiced or carried out in various ways. 
     The present embodiments relate to an inline choke and an angled choke usable with a choke bean to control the flow of drilling fluid to a choke and kill manifold. 
     The inline choke and the angled choke can be used with oil field equipment for providing drilling fluid to the choke and kill manifold or other oil field equipment requiring control of drilling fluid in a well bore. 
     The inline choke and angled choke can each have a choke body with a top and a choke longitudinal bore. 
     In one or more embodiments, the choke body can include an extended body having an upper body that allows drilling fluid to enter the choke before entering a choke bean within the choke. In embodiments, the choke body can have a top that has no extended or upper body above the choke bean. 
     The choke body can have an outer body portion and an inner body portion. The outer body portion can be integral and partially separated from an inner body portion. The outer body portion can include tapered outer sides. 
     A piston cavity can be disposed between the outer body portion and the inner body portion. The piston cavity can support a piston. The piston can have a piston tapered inner edge, a piston upper inner seal face, a piston outer seal face, a piston top, and a piston bottom. 
     The outer body portion and the inner body portion can each have threads, allowing the choke body to be threadably engaged with other components. 
     For example, the choke body can be engaged with a flanged connection, such as an American Petroleum Institute (API) flanged connection. The flanged connection can threadably engage and seal with the outer body portion. 
     The flanged connection can have a flanged connection longitudinal bore axially aligned with the choke longitudinal bore. The flanged connection longitudinal bore can be in fluid communication with the choke longitudinal bore. 
     In one or more embodiments the flanged connection can have a first flanged connection longitudinal bore aligned with the choke longitudinal bore and a second flanged connection longitudinal bore disposed at a right angle to the first flanged connection longitudinal bore. The first flanged connection longitudinal bore can be in fluid communication with the choke longitudinal bore. The second flanged connection longitudinal bore can be in fluid communication with the first flanged connection longitudinal bore. 
     In one or more embodiments, flanged connection threads can be formed along the flanged connection longitudinal bore for threadably engaging with the outer body threads of the choke body. The choke body and the flanged connection can be removable from each other, allowing for individual replacement of each. 
     The flanged connection can have a plurality of flanged connection thru bores formed therein, which can engage fasteners, such as bolts. 
     A studded top connection can be connected to or disposed on a top of the choke body. The studded top connection can be an API connection. 
     A locking plate can be engaged to both the flanged connection and the outer body portion. The locking plate can be engaged on an end of the choke body opposite the top. The locking plate can index the flanged connection to the outer body portion and align the studded top connection with existing oil field equipment. 
     A close port in the choke body can be in fluid communication between a hydraulic control fluid source and the piston cavity for providing hydraulic control fluid to the piston. 
     The inline choke and the angled choke can both include from about one test port to about three test ports. The test ports can be disposed through the choke body, the flanged connection, or both. The test ports can be used to continuously sense pressure in the choke longitudinal bore, the flanged connection longitudinal bore, another section of the choke, or combinations thereof. 
     A choke bean, such as those made by Cameron Iron Works (CIW) or FMC, can be axially disposed in the choke longitudinal bore and threaded to the inner body threads. The choke bean can receive drilling fluid and flow the drilling fluid to the choke and kill manifold. 
     A connecting rod, such as a bolt, can axially extend from the choke bean down the choke longitudinal bore to engage a carbide tip. The carbide tip can be tapered. 
     The carbide tip can be removably engaged with the connecting rod, allowing each to be individually replaced, thereby providing the choke with a modular construction and a longer life span. 
     An elastomeric choke element can be positioned in the choke longitudinal bore between the piston and the carbide tip. The elastomeric choke element can have an elastomeric choke element body, which can be cylindrical. The elastomeric choke element can have an elastomeric choke element outer tapered edge, which can be fitted against the piston. The elastomeric choke element can have an elastomeric choke element tapered thru bore that can be axially aligned with the choke longitudinal bore. 
     A support ring can be disposed between the elastomeric choke element and the flanged connection to keep the elastomeric choke element in the choke body and prevent extrusion of the elastomeric choke element therefrom. 
     In one or more embodiments, an erosion resistant liner can be in the flanged connection longitudinal bore. The erosion resistant liner can be a carbide liner. The erosion resistant liner can be high carbon steel, carbide, ceramic, a ceramic and glass combination, or combinations thereof. 
     A plurality of rod seals can seal between the piston and the outer body, the piston and the inner body, and the inner body and the flanged connection. The rod seals can be elastomeric seals with metal springs or s-rings, such as those made by Utex Industries or James Walker Oil &amp; Gas Company of Houston, Tex. 
     In operation of the inline choke and angled choke, hydraulic control fluid can pass into the close port, and the piston can move in a first direction axially in the choke longitudinal bore. 
     The moving piston can engage the elastomeric choke element and compress the elastomeric choke element around the carbide tip, thereby choking or restricting the drilling fluid passing through the choke bean. 
     The choking or restricting of the drilling fluid passing through the choke bean can enable the choke body to control pressure of the drilling fluid to the choke and kill manifold. 
     When the pressure of the hydraulic fluid is released, the piston can move in a second direction opposite the first direction, and the elastomeric choke element can relax and substantially return to its original shape. 
     In one or more embodiments, the choke studded top connection and the flanged connection can be configured to accommodate oil field equipment having a 1 and 13/16 inch diameter connection, a 2 and 1/16 inch diameter connection, a 2 and 9/16 inch diameter connection, a 3 and 1/16 inch diameter connection, or a 4 and 1/16 inch diameter connection. 
     In embodiments, the elastomeric choke element can be made from a compressible synthetic rubber, a compressible polymer composite having a durometer ranging from about 60 duro to about 90 duro, a hydrogenated nitrile butadiene rubber, another synthetic rubber, a fluoroelastomer, such as VITON® available from DuPont, or combinations thereof. 
     The elastomeric choke element can be configured to withstand temperatures ranging from about −20 degrees Fahrenheit to about 250 degrees Fahrenheit. 
     In one or more embodiments, a plurality of elastomeric choke element inner ridges can be formed in the elastomeric choke element, such as on an elastomeric choke element tapered thru bore. The plurality of elastomeric choke element inner ridges can extend into the choke longitudinal bore. In operation, when the elastomeric choke element is compressed by the piston, the plurality of elastomeric choke element inner ridges can engage the carbide tip, enabling the elastomeric choke element tapered thru bore to engage against the carbide tip for restricting the flow of the drilling fluid. 
     In one or more embodiments, from about two to about eight elastomeric choke element inner ridges can be positioned around the elastomeric choke element tapered thru bore. 
     Turning now to the Figures,  FIG. 1  depicts a cross sectional view of an embodiment of the inline choke  1 . 
     The inline choke  1  can have a top  9 , a bottom  11 , and a choke longitudinal bore  10  disposed through the inline choke  1 . 
     The inline choke  1  can have an outer body portion  12  and an inner body portion  16 , each having different diameters. For example, the inner body portion  16  can have a smaller diameter than the outer body portion  12 , such as a diameter that is about 20 percent smaller than the diameter of the outer body portion  12 . 
     The outer body portion  12  can have tapered sides  14 , which can taper towards a flanged connection  18 . The slope of the tapered sides  14  can range from about 10 degrees to about 30 degrees from the choke longitudinal bore  10 . 
     Proximate the bottom  11 , the inline choke  1  can have a cylindrical outer surface  23  on an outer surface of the outer body portion  12 . 
     Also proximate the bottom  11 , the inline choke  1  can have a seal side  13  on an inner surface of the outer body portion  12 . The cylindrical outer surface  23  can extend parallel to the seal side  13 . 
     A locking plate  26  can be engaged with the cylindrical outer surface  23  and with the flanged connection  18 . The locking plate  26  can have an L-shaped configuration. 
     The locking plate  26  can be engaged with a flanged connection extension  33  on the flanged connection  18 . The flanged connection extension  33  can a have locking plate recesses  37  for receiving the locking plate  26 . 
     The locking plate  26  can align the outer body portion  12  with the flanged connection  18 . The locking plate  26  can be fixed to the flanged connection  18  and removably engaged with the outer body portion  12 . 
     The outer body portion  12  can be threadably engaged with the flanged connection  18 . For example, the outer body portion  12  can have outer body internal threads  15  on the seal side  13 . As such, the outer body portion  12  can have a secure sealed engagement with the flanged connection  18 . 
     The outer body internal threads  15  can threadably engage with flanged connection threads  20 , which can be formed on an outer surface of the flanged connection  18 . 
     The flanged connection  18  can have a flanged connection longitudinal bore  19 , which can be in fluid communication with the choke longitudinal bore  10 . The flanged connection longitudinal bore  19  can be axially aligned with the choke longitudinal bore  10 . 
     The diameters of the flanged connection longitudinal bore  19  and the choke longitudinal bore  10  can range from about 2 inches to about 5 inches. 
     In one or more embodiments, the flanged connection  18  can have a base with a diameter ranging from about 8 inches to about 14 inches, and a body extending from the base with a diameter ranging from about 4 inches to about 8 inches. 
     An erosion resistant liner  72 , such as a carbide liner, can line the flanged connection longitudinal bore  19 . The erosion resistant liner  72  can have a thickness ranging from about 0.01 inches to about 0.3 inches. 
     The inline choke  1  can have inner body threads  17  at the top  9 . The inner body threads  17  can threadably engage with a choke bean  32 . 
     The choke bean  32  can be positioned within the choke longitudinal bore  10 . The choke bean  32  can transfer drilling fluid  3  from a drilling fluid source, such as a mud pump or another source, to the flanged connection longitudinal bore  19 . 
     The choke longitudinal bore  10  can open into an annular recess  24 . The annular recess  24  can support an elastomeric choke element  44 . 
     The inner body portion  16  and the outer body portion  12  can be separated by a piston cavity  25 . A piston  50  can be contained within the piston cavity  25 . The piston cavity  25  can extend into the annular recess  24  without extending into the choke longitudinal bore  10 . 
     The piston cavity  25  can support the piston  50 . In operation, the piston  50  can push against the elastomeric choke element  44  when hydraulic control fluid  35  flows into a close port  28  of the inline choke  1 . 
     The piston  50  can have a piston upper inner seal face  54 , a piston outer seal face  56 , a piston top  58 , and a piston bottom  60 . In operation, the piston top  58  can be directly engaged by the hydraulic control fluid  35 . 
     The inline choke  1  can have first piston seals  66   a  and  66   b , which can seal in parallel on the piston outer seal face  56 . 
     The inline choke  1  can have first rod seals  68   a  and  68   b , which can seal the piston upper inner seal face  54  to the inner body portion  16 . 
     The inline choke  1  can have second rod seals  70   a  and  70   b , which can seal the seal side  13  to the flanged connection  18 . 
     The elastomeric choke element  44  can have a thru bore  47 , which can be an elastomeric choke element body tapered thru bore. The elastomeric choke element  44  can have an elastomeric choke element outer tapered edge  46 , which can engage a piston tapered inner edge  52  of the piston  50 , allowing the piston  50  to apply pressure to the elastomeric choke element  44  to compress the elastomeric choke element  44 . 
     The piston  50  can be driven in a first direction, also called the close direction, by the hydraulic control fluid  35 , which can be introduced through the close port  28 . The close port  28  can extend from the outer body portion  12  to the piston cavity  25  to allow the hydraulic control fluid  35  to engage the piston  50 . 
     A first test port  30  can be disposed through the outer body portion  12  and into the choke longitudinal bore  10 . The first test port  30  can allow an operator to test for pressure in the choke longitudinal bore  10  near the choke bean  32 . 
     In operation, the choke bean  32  can receive the drilling fluid  3  and control the flow of the drilling fluid  3 . 
     The choke bean  32  can have a connecting rod  36  extending from one end of the choke bean  32 . The connecting rod  36  can be threaded onto a carbide tip  40 , which can be tapered. 
     The connecting rod  36  can have a threaded portion  38  to ensure a secure and removable engagement between the connecting rod  36  and the carbide tip  40 . The carbide tip  40  can extend into the thru bore  47 . 
     The thru bore  47  can have a plurality of elastomeric choke element inner ridges, such as elastomeric choke element inner ridge  48 , extending into the thru bore  47 . The inline choke  1  can include from about two elastomeric choke element inner ridges to about ten elastomeric choke element inner ridges. The elastomeric choke element inner ridges  48  can have rounded edges or other shapes. 
     In operation, the elastomeric choke element outer tapered edge  46  can push against the piston tapered inner edge  52  of the piston  50 , allowing the piston  50  to compress the elastomeric choke element  44  longitudinally. As such, the elastomeric choke element  44  can form a choke with the carbide tip  40  to restrict flow of the drilling fluid  3 . 
     The elastomeric choke element  44  can be supported in the choke longitudinal bore  10  by a support ring  42 , which can prevent the elastomeric choke element  44  from compressing out of the annular recess  24  and into the choke longitudinal bore  10 , which could damage the inline choke  1 . 
       FIG. 2  depicts a perspective view of the inline choke of  FIG. 1  with the flanged connection  18  connected to the choke body  8 . The choke body  8  can be made of steel. 
     The flanged connection  18  can have a plurality of flanged connection thru bores, such as flanged connection thru bores  22   a  and  22   f . The plurality of flanged connection thru bores  22   a  and  22   f  can be disposed about the flanged connection  18 . 
     Fasteners, such as fastener  73 , can engage through each flanged connection thru bore  22   a  and  22   f  to fasten the inline choke  1  to a flange connection on a choke and kill manifold. The fasteners  73  can be bolts. 
     The locking plate  26  can be removably fastened to a flanged connection extension  33  and the cylindrical outer surface  23  for aligning the choke body  8  with the flanged connection  18 . 
     Locking plate fasteners  39  can removably attach the locking plate  26  to the choke body  8 . 
     This Figure also shows that the inline choke  1  can have an API studded top connection  21  and the close port  28  can be disposed through the choke body  8 . 
       FIG. 3  depicts a cross sectional view of an angled choke  2 . The angled choke  2  is shown having a choke body  8  with a choke longitudinal bore  10 . 
     The angled choke  2  can have an angled flanged connection  118  having a right angle conduit  122  engaged with an API connector  120 . The API connector  120  can connect the angled choke  2  to a gate valve or similar device in the choke and kill manifold. 
     The angled flanged connection  118  can have a central conduit  124  axially aligned and in fluid communication with the choke longitudinal bore  10 . The central conduit  124  is also referred to as a first flanged connection longitudinal bore. The right angle conduit  122  can be in fluid communication with the central conduit  124 , allowing the angled choke  2  to be used to replace existing chokes. The right angle conduit  122  is also referred to herein as a second flanged connection longitudinal bore. 
     A first test port  30  can be used to determine pressure in the choke longitudinal bore  10 . The angled flanged connection  118  can have a second test port  31 , which can be used to determine pressure in the central conduit  124 , the right angle conduit  122 , or combinations thereof. 
     The first test port  30  and the second test port  31  can be used to simultaneously and continuously determine pressures before the piston  50  compresses the elastomeric choke element  44 , during compression of the elastomeric choke element  44  by the piston  50 , and after the piston  50  compresses the elastomeric choke element  44 . 
     Also shown are the choke bean  32 , the carbide tip  40 , the close port  28 , the locking plate  26 , and the erosion resistant liner  72 . 
       FIG. 4  depicts another embodiment of an angled choke  4 . The angled choke  4  can have a right angle studded API connection  126  in fluid communication with the choke bean  32 . 
     The angled choke  4  can have an upper body  128  with an upper body longitudinal bore  130 . The upper body longitudinal bore  130  can have an access plug  132  disposed therein. 
     An upper test port  133  can be disposed through the access plug  132  for providing access to test pressure in the right angled studded API connection  126 . 
     The access plug  132  can be sealed in the upper body longitudinal bore  130  with seals  135   a  and  135   b . The seals  135   a  and  135   b  can be elastomeric seals or piston seals. 
     The access plug  132  can be threadably engaged with the upper body longitudinal bore  130 , allowing for insertion and removal of the access plug  132  for maintenance, easy repair, and replacement of the choke bean  32 . 
     Also shown is the choke bean  32  in the choke longitudinal bore  10 , the close port  28 , the flanged connection  18 , and the erosion resistant liner  72 . 
       FIG. 5  depicts a perspective view of the angled choke  4  of  FIG. 4  showing the right angled studded API connection  126 , the choke body  8 , the flanged connection  18 , upper test port  133 , and the access plug  132 . 
       FIG. 6A  depicts a flanged connection fastener  129   a  engaged into a choke body fastener hole  127   a , connecting the flanged connection  18  to the choke body  8 . 
       FIG. 6B  is a view along line A-A of  FIG. 6A , and depicts the flanged connection fasteners  129   a  and  129   h  engaged into the choke body fastener holes. 
     The flanged connection fasteners  129   a  and  129   h  and the choke body fastener holes can be used in place of the locking plate or in addition to the locking plate. 
       FIG. 7  depicts an embodiment of the inline choke  1  with a carbide tip  40  having a counter bore  41  axially aligned with the choke longitudinal bore  10 . 
     The carbide tip  40  with the counter bore  41  can slidably and removably engage a connecting rod  36 . 
     A locking nut  43  can engage the connecting rod  36  with the choke bean  32 . 
     The configuration of the carbide tip  40 , the connecting rod  36 , the counter bore  41 , and the choke bean  32  as depicted in  FIG. 7  can be incorporated into the other embodiments of the inline choke and angled choke disclosed herein. 
     While these embodiments have been described with emphasis on the embodiments, it should be understood that within the scope of the appended claims, the embodiments might be practiced other than as specifically described herein.