Patent Publication Number: US-2022213756-A1

Title: Inverted diffuser for abrasive slurry flow with sensor for internal damages

Description:
CROSS REFERENCE TO RELATED APPLICATIONS 
     This application is a Continuation of U.S. patent application Ser. No. 16/845,213 titled “INVERTED DIFFUSER FOR ABRASIVE SLURRY FLOW WITH SENSOR FOR INTERNAL DAMAGES,” filed Apr. 10, 2020, the full disclosure of which is incorporated herein by reference herein for all intents and purposes. 
    
    
     BACKGROUND 
     1. Field of Invention 
     This invention relates in general to equipment used in the hydrocarbon industry, and in particular, to an inverted diffuser having at least one releasable section to mix and guide abrasive slurries in a wellhead or other wellsite equipment. 
     2. Description of the Prior Art 
     A fracturing tree with a fracturing wellhead may be used in a fracturing process to assist in hydrocarbon production from subterranean environments. To improve permeability of the subterranean environments, the fracturing process is applied to fracture formation levels of the subterranean environment. In an example, fluids may be pumped under higher pressure through the wellhead as part of the fracturing process. The fluids may include components, such as a liquid component and proppants. The proppants include one or more of sand, bauxite, and other particulate abrasives. The fluids are also referred to as abrasive slurries in the present disclosure. 
     The abrasive slurry, such as water and proppant mixed together, may be pumped through the subterranean formation through the fracturing tree. Gas fields or wellsites that are under development may require higher flow rates of the mixture that may be delivered through one or more injection lines. The flow of components from the one or more injection lines may be mixed together in a chamber of the fracturing wellhead. The fracturing wellhead guides the mixture with the abrasive slurries to a wellbore casing. As the diameter of the chamber of the fracturing wellhead is larger than the casing diameter, a reduction in diameter may be provided via a reducer or segment of the wellhead prior to guiding the abrasive slurries into the casing. As the abrasive slurries mix and flow at high flowrates, the reducer is subject to material erosion and its working life may be reduced. This increases operational costs as the reducer may be required to be replaced. 
     SUMMARY 
     An inverted diffuser for wellhead and wellsite equipment is disclosed. The system includes at least one first section having a first vertical inner surface, a first inclined inner surface relative to the first vertical inner surface, and one or more channels supporting one or more releasable fasteners between the at least one first section and a wall of a wellhead or of a wellsite equipment. The system also includes at least one second section having a second vertical inner surface and a second inclined inner surface relative to the second vertical inner surface. The at least one second section is press-fitted or fastened adjacent to the at least one first section in the system. 
     A method for application of an inverted diffuser that uses at least one releasable section in a wellhead is also disclosed. The method includes placing a first one of the at least two releasable sections into the wellhead or the wellsite equipment. The at least two releasable sections have a first vertical inner surface and a first inclined inner surface relative to the first vertical inner surface. The method also includes placing a second one of the at least two releasable sections into the wellhead or the wellsite equipment adjacent to the first one of the at least two releasable sections. The method further includes fastening the first one of the at least two releasable sections to a wall of the wellhead using one or more releasable fasteners within one or more channels of the first one of the at least two releasable sections so that the at least two releasable sections are held in place against the wall of the wellhead or the wellsite equipment. 
     A method for manufacturing an inverted diffuser for a wellhead is additionally disclosed. The method includes determining dimensions of a segment of the wellhead that is adapted to include the inverted diffuser. A further step in the method is machining, based at least in part on the dimensions, at least two releasable sections to include, on individual first sides of the at least two releasable sections, a vertical inner surface and a inclined inner surface relative to the vertical inner surface. The method includes drilling one or more channels into an individual second side of at least one of the at least two releasable sections and threading the one or more channels to receive one or more releasable fasteners. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
       Various embodiments in accordance with the present disclosure will be described with reference to the drawings, in which: 
         FIG. 1  illustrates an example wellhead subject to improvements of the present embodiments. 
         FIG. 2A  is a perspective view of a wellhead incorporating an aspect of an inverted diffuser having at least two releasable sections to mix and guide abrasive slurries, in accordance with an embodiment in the present disclosure. 
         FIG. 2B  is a cross-section view of a wellhead incorporating the inverted diffuser, such as from  FIG. 2A , in accordance with an aspect of the disclosure. 
         FIG. 3  is a cross-section view of a wellhead incorporating a further aspect of an inverted diffuser having at least two releasable sections, in accordance with an embodiment in the present disclosure. 
         FIG. 4  is a cross-section view of a wellhead incorporating yet another aspect of an inverted diffuser having at least two releasable sections, in accordance with an embodiment in the present disclosure. 
         FIG. 5A  illustrates different views of an inverted diffuser having at least two releasable sections, in accordance with an aspect in the present disclosure. 
         FIG. 5B  illustrates a perspective view of sections forming an inverted diffuser, such as the inverted diffuser of  FIG. 5A , in accordance with an aspect in the present disclosure. 
         FIG. 6  illustrates plan views of different arrangements of sections for inverted diffusers having at least two releasable sections, in accordance with aspects in the present disclosure. 
         FIG. 7  illustrates a process flow of a method for application of an inverted diffuser that uses at least two releasable sections in a wellhead or other wellsite equipment, in accordance with an embodiment in the present disclosure. 
         FIG. 8  illustrates a process flow of a method for manufacturing an inverted diffuser having at least two releasable sections for use within a wellhead or other wellsite equipment, in accordance with an embodiment in the present disclosure. 
     
    
    
     DETAILED DESCRIPTION 
     In the following description, various embodiments will be described. For purposes of explanation, specific configurations and details are set forth in order to provide a thorough understanding of the embodiments. However, it will also be apparent to one skilled in the art that the embodiments may be practiced without the specific details. Furthermore, well-known features may be omitted or simplified in order not to obscure the embodiment being described. 
     Various other functions can be implemented within the various embodiments as well as discussed and suggested elsewhere herein. In at least an aspect, the present disclosure is to an inverted diffuser having at least one releasable section to mix and guide abrasive slurries in a wellhead or other wellsite equipment. 
     Replaceable sleeves may include higher hardness material and may be used in parts of the fracturing wellhead. Such sleeves may be cylindrical in shape and may be installed through a bore of the fracturing head, such as from the top or from the bottom of the fracturing head. The replaceable sleeves may be inserted into the fracturing head through a continuous cavity and may be locked in place using a flange or auxiliary block in the wellhead. Furthermore, a polymeric coating may be applied to the replaceable sleeve, but its effect is limited to prevent degradation or damage when the abrasive slurries are flowing at very high flowrates (e.g., 220 barrels per minute (bpm) or 42 U.S. gallons per minute). As a matter of reference, present flow rate that may exist on lower to mid flowrate equipment is about 110 bpm. Still further, a replaceable sleeve that is directly inserted into the fracturing head can include the mix chamber in the sleeve, but such an implementation experiences erosion issues because of the location and makes replacement time consuming. 
     In at least one aspect, the present disclosure is for an inverted diffuser that has sections that can be inserted into the larger diameter of the fracturing head through a smaller bore and locked in place with fasteners, such as bolts, to a segment of the fracturing head. The sections may be determined based in part on the dimensions of the segment of a mixing chamber in the fracturing head. For instance, the number of sections as well as dimensions of the sections may be based in part on the internal dimensions of the segment. The sections, therefore, may be designed to have a cross-section dimension smaller or lesser than a through-bore diameter of segment of the fracturing wellhead where the inverted diffuser will be located. This dimensioning process allows inserting of the sections through the bore and allows installing of the sections on inner walls of the inverted diffuser segment of the mixing chamber. 
     In at least one aspect, the sections may be made entirely or partly (e.g., surface coated) with a tougher or harder material. In at least one instance, the sections may be carbide-coated. The tougher or harder material reduces erosion of the inverted diffuser as the abrasive slurries flow through the segment and are subject to reduction in cross-section to the subsequent bore. In the event of damage during operation, the sections may be replaced, thereby extending life of the fracturing head. The present inverted diffuser may be applied in wellheads and in other wellsite equipment that maybe other than subterranean, including surface or subsea equipment, that experience erosion due to abrasive slurries within limited areas to provide surface or material protection. 
     In at least one aspect, channels or holes are drilled into the segment and at least partly through the sections to allow the installation of the sections against inner walls of the segment and to allow releasable fastening of the sections to the inner walls using fasteners from the outside wall of the segment. In at least one aspect, bolts may serve as the fasteners to secure the sections in place or in location. The bolts may have a bolt head and are screwed through the channel of the segment to the channel of the sections (at its back side), but may not extend to a front side of the sections that includes the toughened or hardened material and that is exposed to the abrasive slurries. The channels of the segment also enable pressure sensors to be coupled thereon, with a gap maintained between the pressure sensors and the head of the bolts. This enables a sub-system to determine possible degradation of the sections. For instance, a change in the pressure in the gap may be a result of a leak from within the chamber. An operator may monitor the sub-system to determine damage or degradation of internal parts, such as the sections. 
     In at least one aspect, the sections or internal walls of the fracturing head may be damaged or eroded as a result of managing the abrasive slurries. When the damage or erosion is to a point where some leak is experienced through the channels forming the bolt holes of the segment, such as from behind the sections or between the sections and through the sections&#39; channels to the segment&#39;s channels, the leak is detected or indicated by a pressure change (e.g., increased pressure) in the monitoring sub-system. The threshold of damage or degradation may be the leak and the pressure change may be asserted from prior leaks correlated to prior pressure changes or to new leaks causing new pressure changes. In at least one aspect, based in part on the pressure sensor inside the channels of the segment of the fracturing head, the sections may be replaced as necessary. This allows embedded technology that can withstand higher flow rates for certain applications using the same fracturing head. Certain applications may require higher flow rates for the abrasive slurries that could cause rapid erosion of the inverted diffuser. 
     In at least one aspect, computational fluid dynamics (CFD) simulations indicate an erosion rate of 0.030 inches per hour for the inverted diffuser of the present disclosure, when the abrasive slurries are flowing at about 220 bpm through the reducer of the fracturing head. On the straight bore, the erosion rate indicates 0.0015 inches per hour at the same flowrate level, which reflects that the bore area is subject to 20 times lower erosion features than in the reducer area. The tougher or harder material in the inverted diffuser sections of the present disclosure may extend the life of the reducer segment by allowing reuse of the same segment and the fracturing head by only replacing the sections of the inverted diffuser. The pressure monitoring sub-system may be calibrated and the calibrations may be used to train a learning system to indicate to an operator when the sections may need replacement. For instance, using a multi-node neural network trained to correlate leaks through the channel gaps of the segment holding the sections to pressure changes monitored off of pressure sensors, the monitoring sub-system may be adapted to determine the pressure or pressure changes that are outside a threshold or that do not satisfy a threshold. This indication of the pressure or the pressure changes being outside of or not satisfying the threshold may be indication of degradation, such as erosion or other failure of the sections; and this indication may be used to consider changing the sections, for instance. 
     Examples of a computer system or feature operable within the monitoring sub-system may include a computer-readable medium that may be enabled for communications with external devices for communicating at least pressure information or pressure changes. In addition, the computer system included at the well site or remotely, may include multi-processor capabilities to train and test neural networks to correlate the pressure and the degradation information gathered over at least a few cycles of operation of an inverted diffuser. Such a computer system may include one or more nonvolatile, hard-coded type media, such as read only memories (ROMs), or erasable, electrically programmable read only memories (EEPROMs); recordable type media, such as flash drives, memory sticks, and other newer types of memories; and transmission type media such as digital and analog communication links. For example, such media can include operating instructions, as well as instructions related to the systems and the method steps described previously and can operate on a computer. It will be understood by those skilled in the art that such media can be at other locations instead of, or in addition to, the locations described to store computer program products, e.g., including software thereon. It will be understood by those skilled in the art that the various software modules or electronic components described previously can be implemented and maintained by electronic hardware, software, or a combination of the two, and that such embodiments are contemplated by embodiments of the present disclosure. 
       FIG. 1  illustrates an example wellhead  100  subject to improvements in the present embodiments. Wellhead  100  includes a main bore  108  and side bores  122 ,  124  within a wellhead body  118 . The wellhead  100  also includes multiple ports  102 - 106  to access the bores  108 ,  122 ,  124 . The bores  108 ,  122 ,  124  are fluidly coupled together to enable mixing of the components provided through the ports  102 - 106 . A flange  120  is provided to couple a through-bore  116  of smaller diameter than the main bore  108 . Reducer  114  is provided either integral to the wellhead body  118  or as part of a segment associated with the wellhead body  118 . In an example, an additional flange may be provided between the wellhead body  118  and the flange  120  to include the reducer  114 . The reducer  114  enables an inverted diffuser to facilitate mixing of components forming the abrasive slurries. 
     The ports  102 - 106  enable connection to receive high-pressure lines for passing abrasives and other components, including fluids, from a high-pressure pump into the wellhead&#39;s main bore  108 . The components, under high pressure endure vigorous agitation in the main bore  108  as the components enter from the side bores  122 ,  124  before being forced through the narrowing of the reducer providing additional diffusing of the components forming the abrasive slurry that then passes through the bore  116  of flange  120  for the fracturing process. Further, valves  110 ,  112  are provided for killswitch or choking functions. 
       FIG. 2A  is a perspective view of a wellhead  200  incorporating an aspect of an inverted diffuser having at least one releasable section to mix and guide abrasive slurries, in accordance with an embodiment in the present disclosure. Wellhead  200  includes a main port  202  providing access to a main bore and side ports  204 ,  206  providing access to side bores within a wellhead body  208 . A person of ordinary skill would understand that the port and subsequent bores may be of wider inner diameter than illustrated and the bore walls are not proportionally illustrated in the present figures. The bores are fluidly coupled together to enable mixing of the components provided through the ports  202 - 206 . A segment  214  is provided to couple the main bore to a reducer having the inverted diffuser, which is further illustrated in  FIG. 2B , for instance. The reducer may be further coupled to a through-bore of smaller diameter than the main bore. The reducer is illustrated as part of the segment  214  that is separated from the wellhead body  208 , but that is coupled to the wellhead body  208  using bolts  212  on at least a flange  210 . In an example, an additional flange may be provided between the segment  214  and a further through-bore below the reducer. 
       FIG. 2A  also illustrates that the segment  214  has one or more pressure sensors  216 A,  216 B associated with channels within the segment  214 . The one or more pressure sensors  216 A,  216 B are releasably coupled to the one or more second channels with respective gaps maintained between the one or more pressure sensors  216 A,  216 B and a respective one or more of the individual heads of one or more bolts that hold the one or more sections in place within the segment  214 . Furthermore, while two of the channels are illustrated without pressure sensors, a person of ordinary skill would recognize, upon reading the present disclosure, that further pressure sensors, as many as required for an application, may be applied in the available one or more channels. 
     The ports  202 - 206  enable connection to receive high-pressure lines for passing abrasives and other components, including fluids, from a high-pressure pump into the wellhead&#39;s main bore. The components, under high pressure endure vigorous agitation in the main bore as the components enter from the side bores before being forced through the narrowing of the reducer providing additional diffusing of the components forming the abrasive slurry that then passes through a connected bore below the reducer for the fracturing process. 
     Further, in at least one aspect, the pressure sensors are able to monitor for any abnormal internal erosion in the fractural head, before any catastrophic failure. For instance, signals or values communicated from one or more pressure sensors  216 A,  216 B are processed in at least one processor of monitoring module or sub-system  220 . The at least one processor, in an example, may be adapted to execute instructions for a multi-node neural network trained to correlate leaks through the channel associated with the bolts of the segment to pressure changes monitored off of the pressure sensors. The monitoring module or sub-system  220  may be adapted to determine the pressure or pressure changes that are outside a threshold or that do not satisfy a threshold. This indication of the pressure or the pressure changes being outside of or not satisfying the threshold may be indication of degradation, such as erosion or other failure of the sections; and this indication may be used to consider changing the sections, for instance. 
     Once erosion is detected to a point that the indication is made, an operator may replace the sections of the inverted diffuser with a new set of sections, but the fracturing head or the segment upon which the sections are mounted can continue to remain in operation with the new set of sections. Such a solution enables the wellsite equipment to have a longer life by planning for requirement maintenance based in part on the intelligent monitoring of the pressure sensors to reduce the risk of catastrophic failure. Moreover, the longer the endurance for wellsite equipment, the lesser the downtime periods for operations on the wellsite. This also enables reduced logistics for shipping of heavy equipment required to conduct the maintenance if a new fracturing wellhead is required. Cost savings achievable from the present aspects is also associated with a reduced number of fracturing wellheads that may be required to complete a fracturing process or operation at a wellsite; and particularly when high flowrates (e.g., 220 bpm) of the abrasive slurries are required. 
       FIG. 2B  is a cross-section view of a wellhead  250  incorporating the inverted diffuser, such as from  FIG. 2A , in accordance with an aspect of the disclosure. The inverted diffuser is formed of an arrangement of sections that include a vertical surface  292  below an inclined surface  294 . At least two of the sections are illustrated in the cross-section as reference numerals  284 ,  286 . Further, the segment  268  coupled to the wellhead body  264  via bolts  290  (one bolt is illustrated) and may be referred to as a reducer section for including the reducer  270  formed of the inverted diffuser sections. A first section  284  and at least one second section  286  of the inverted diffuser are provided so that at least one of the two sections may be fastened to a wall of the wellhead or wellsite equipment. There may be other configurations of the at least two sections. In an aspect, the at least one first section has one or more channels  278  to receive a fastener, such as a bolt that holds the at least one first section to a wall of the segment  268 . The at least one second section may similarly include one or more channels to receive a fastener, such as a bolt that holds the at least one second section to a wall, or the at least one second section may, differently from the at least one second section, not include the one or more channels and may be held in place by a press-fit against the wall of the segment  268  and the at least one first section that is fastened to the wall. Press-fit refers to positioning a section against one or more sections and the wall so that at least surface friction from the one or more sections and the wall hold the section in place. As such, at least one against section of the one or more sections may be fastened using or more bolts as in the aspects throughout this disclosure. The act of press-fitting refers to achieving the press-fit for the section requiring press-fit with another section, for instance. 
     In at least one aspect, the arrangement of sections may include two second sections forming the at least one second section, and with the two second sections being press-fitted with the at least one first section that is fastened to the wall of the segment. Alternatively, the arrangement of sections may include two first sections forming the at least one first section that are fastened to the wall of the segment, and two second sections forming the at least one second section which are both press-fitted with the two first sections. In a further alternative, the arrangement of sections may include the at least one second section that is adapted to be fastened to the wall along with, and located adjacent to, the at least one first section. In yet another alternative arrangement of the section, two or three second sections with adaptations to be fastened may be provided to form the at least one second section and to be fastened to the wall along with, and adjacent to, the at least one first section. 
       FIG. 2B  also illustrates that at least one of the sections (e.g., at least one first section  286 ) may include a vertical inner surface  292 , a inclined inner surface  294  relative to the vertical inner surface  292 , and one or more first channels  278  supporting one or more releasable fasteners  272  between the at least one first section  286  and a wall  296  of a wellhead or of a wellsite equipment  250 . For illustrative purposes only one first channel of the four illustrated channels—as readily apparent from the figure—is marked by the reference numeral. Further, at least one of the sections (e.g., at least one second section  284 ) may include a second vertical inner surface and a second inclined inner surface relative to the second vertical inner surface, so that the at least one second section may be press-fitted or fastened adjacent to the at least one first section. As  FIG. 2B  illustrates similar symmetrical arrangement of at least two sections  284 ,  286 , a person of ordinary skill reading the present disclosure can infer description for the at least one section  284 , as to a second vertical inner surface and a second inclined inner surface included therein, from the description provided with respect to the at least one first section  286  (and the descriptions made with reference to the other figures herein). A person or ordinary skill would also recognize that the cross-section shows limited views of the arrangement of the sections and further sections than the sections  284 ,  286  already described may be included circumferentially within the reducer  270 . Example arrangements of the sections are provided in at least  FIGS. 5A, 5B, and 6 . 
     Further, when the at least one second section  286  is not provided with ability to receive fasteners, one or more side surfaces (e.g., sides  562 A,  562 B on section  554 B in  FIG. 5B ) on the at least one second section  286  enable press-fitting of the at least one second section  286  with the at least one first section  284  which is fastened within the wellhead or the wellsite equipment  250 . Still further, the segment  268  has one or more second channels  276  (one channel of the four illustrated channels—as readily apparent from the figure—is marked by the reference numeral) for supporting the one or more releasable fasteners  272  (one of the four fasteners is marked for illustrative purpose) from an outer surface  288  of the segment  268  to the at least one first section  286 . 
       FIG. 2B  also illustrates that the fasteners  272  may be one or more bolts. Each bolt includes a bolt head  272 B and a bolt body  272 A for threading in a respective first channel (e.g., first channel  278 ). As the bolts are removable, they form the one or more releasable fasteners. Further, as the bolts are adapted to thread within the one or more first channels, the depth the bolts reach enables individual heads of the one or more bolts to be partly within the one or more second channels (e.g., second channel  276 ). The one or more pressure sensors (e.g., pressure sensor  280 ,  288 ) are releasably coupled to the one or more second channels with respective gaps (e.g., gap  274 ) maintained between the one or more pressure sensors and a respective one or more of the individual heads. 
       FIG. 2B  also illustrates that wellhead  250  includes a main port  252  providing access to a main bore  266  and side ports  254 ,  256  providing access to side bores  260 ,  262  within a wellhead body  258 . The bores  260 ,  262 ,  266  are fluidly coupled together to enable mixing of the components provided through the ports  252 - 256 . The segment  268  is provided to couple the main bore  266  to a reducer  270  (having reducer opening  258 ) having the inverted diffuser sections. The reducer  270  may be further coupled to a through-bore  282  of smaller diameter than the main bore  266 . The reducer is illustrated as part of the segment  268  that is separated from the wellhead body  264 , but that is coupled to the wellhead body  264  using bolts  290  (one bolt is illustrated) on at least a flange. In an example, an additional flange may be provided between the segment  214  and the further through-bore  282  below the reducer.  FIG. 2B  illustrates that the sections  284 ,  286  are sufficiently dimensioned to be able to pass through the reducer opening  258  or through the main port  252  and bore  266  to the location in the reducer  270 , prior to being fastened or press-fitted in position. 
       FIG. 3  is a cross-section view of a wellhead  300  incorporating a further aspect of an inverted diffuser having at least one releasable section, in accordance with an embodiment in the present disclosure. The embodiment of  FIG. 3  illustrates an inverted diffuser that is formed of an arrangement of sections, illustrated in the cross-section as reference numerals  334 ,  336 , and that are positioned closer to an opening  308  of the segment  318 . Further, the segment  318  is attached to the wellhead body  314  via at least bolts  340  (one bolt is illustrated). A first section  334  and at least one second section  336  of the inverted diffuser are provided so that at least one of the two sections (e.g., at least the first section  334 ) may be fastened to a wall of the wellhead or wellsite equipment. As previously described in reference to the embodiment in  FIG. 2B , the configuration of the at least two sections in  FIG. 3  is so that the at least one second section  336  is press-fit with the at least one first section  334 . 
     In at least one aspect, the at least one first section  334  has one or more channels (one is illustrated with reference numeral  328 ) to receive a fastener, such as a bolt that holds the at least one first section  334  to a wall  318 A of the segment  318 . The at least one second section  336 , differently from the at least one second section, does not include the one or more channels and may be held in place by a press-fit against the wall  318 B of the segment  318  and the at least one first section  334  that is fastened to the wall. As the illustration in  FIG. 3  is a cross-section, one or ordinary skill would recognize that the wall is an inner circumference of the segment  318 , and that reference numerals  318 A,  318 B refer to the same wall, but at different locations. Further, in at least one aspect, the segment  318  opens directly to the reducer section  320 , via opening  308 , without a need for a vertical section illustrated in the opening of the reducer  270  of  FIG. 2B . As such,  FIGS. 2B and 3  illustrate that the sections may be adapted to fix at different determined locations within the segment intended to include a reducer in a wellhead or other wellsite equipment. 
       FIG. 3  also illustrates that at least one of the sections (e.g., at least one second section  336 ) may include a vertical inner surface  342  and a inclined inner surface  344  relative to the vertical inner surface  342 . In the embodiment of  FIG. 3 , the at least one first section  334  includes the one or more first channels  328  supporting one or more releasable fasteners  322  between the at least one first section  334  and the wall  318 A of the wellhead or of the wellsite equipment  300 . For illustrative purposes only one first channel of the two illustrated channels—as readily apparent from the figure—is marked by the reference numeral. Further, the at least one second section  336  is not illustrated to include fasteners in the cross-section, but the fasteners may be located elsewhere in an outer circumference of the section  336  or the section  336  may be designated for being press-fitted adjacent to the at least one first section  334 . As  FIG. 3  illustrates similar symmetrical arrangement of at least two sections  334 ,  336 , a person of ordinary skill reading the present disclosure can infer description for the at least one first section  334 , as to a second vertical inner surface and a second inclined inner surface included therein, from the description provided with respect to the at least one second section  226  (and the descriptions made with reference to the other figures herein). 
       FIG. 3  also illustrates that the fasteners  322  may be one or more bolts. Each bolt includes a bolt head and a bolt body for threading in a respective first channel (e.g., first channel  328 ). As the bolts are removable, they form the one or more releasable fasteners. Further, as the bolts are adapted to thread within the one or more first channels, the depth the bolts reach enables individual heads of the one or more bolts to be partly within the one or more second channels (e.g., second channel  326 ). The one or more pressure sensors (e.g., pressure sensor  330 ,  338 ) are releasably coupled to the one or more second channels with respective gaps (e.g., gap  324 ) maintained between the one or more pressure sensors and a respective one or more of the individual heads. 
       FIG. 3  also illustrates that wellhead  300  includes a main port  302  providing access to a main bore  316  and side ports  304 ,  306  providing access to side bores  310 ,  312  within a wellhead body  314 . The bores  304 ,  306 ,  316  are fluidly coupled together to enable mixing of the components provided through the ports  302 - 306 . The segment  318  is provided to couple the main bore  316  to a reducer  320  (having reducer opening  308 ) having the inverted diffuser sections. The reducer  320  may be further coupled to a through-bore  332  of smaller diameter than the main bore  316 . The reducer  320  is illustrated as part of the segment  318  that is separated from the wellhead body  314 , but that is coupled to the wellhead body  314  using bolts  340  (one bolt is illustrated) on at least a flange. In an example, an additional flange may be provided between the segment  318  and the further through-bore  332  below the reducer.  FIG. 3  also illustrates that the sections  334 ,  336  are sufficiently dimensioned to be able to pass through the reducer opening  308  or through the main port  302  and bore  316  to the location in the reducer  320 , prior to being fastened or press-fitted in position. 
       FIG. 4  is a cross-section view of a wellhead  400  incorporating yet another aspect of an inverted diffuser having at least one releasable section, in accordance with an embodiment in the present disclosure. The embodiment of  FIG. 4  illustrates an inverted diffuser that is formed of an arrangement of sections and that includes multiple vertical surfaces  432 A,  432 B, and at least one prominent inclined surface  438 . Additional inclined surfaces may exist, such as an inclined surface to enabling coupling the diameter of the segment  418  with through-bore  442 , but the inclined surface  438  in the center of reducer  420  enables agitation and mixing in the inverted diffuser. Two of the sections are illustrated in the cross-section as reference numerals  434 ,  436 . Further, the segment  418  is integral in the wellhead body  414 . A first section  434  and at least one second section  436  of the inverted diffuser are provided so that at least one of the two sections (e.g., either of the at least one first section  434  and/or the at least one second section  436 ) may be fastened to a wall of the wellhead or wellsite equipment. As previously described in reference to the embodiment in  FIG. 2B , the configuration of the at least two sections in  FIG. 4  is so that no press-fit is required and all sections may be fastened to the wall of the wellhead body  414  at segment  418 . 
     In at least one aspect, the at least one first section  434  has one or more channels (one is illustrated with reference numeral  428 ) to receive a fastener, such as a bolt that holds the at least one first section  434  to a wall of the segment  418 . The at least one second section  436  also includes the one or more channels to fasten the at least one second section  436  to the wall. As the illustration in  FIG. 4  is a cross-section, one or ordinary skill would recognize that the wall is an inner circumference of the segment  418 , and that reference to the wall for both sections refer to the same wall, but at different locations. Further, in at least one aspect, the segment  418  opens to the reducer section  420 , via opening  408 , with a vertical section illustrated in the bore  416  prior to reaching the vertical surface  432 A of the inverted diffuser sections. Therefore, in a similar manner as in  FIGS. 2B and 3 ,  FIG. 4  also illustrates that the sections may be adapted to fix at different determined locations within the segment intended to include a reducer in a wellhead or other wellsite equipment. 
       FIG. 4  also illustrates that the fasteners  422  may be one or more bolts. Each bolt includes a bolt head and a bolt body for threading in a respective first channel (e.g., first channel  428 ). As the bolts are removable, they form the one or more releasable fasteners. Further, as the bolts are adapted to thread within the one or more first channels, the depth the bolts reach enables individual heads of the one or more bolts to be partly within the one or more second channels (e.g., second channel  426 ). The one or more pressure sensors (e.g., pressure sensor  430 ,  440 ) are releasably coupled to the one or more second channels with respective gaps (e.g., gap  424 ) maintained between the one or more pressure sensors and a respective one or more of the individual heads. 
       FIG. 4  also illustrates that wellhead  400  includes a main port  402  providing access to a main bore  416  and side ports  404 ,  406  providing access to side bores  410 ,  412  within a wellhead body  414 . The bores  404 ,  406 ,  416  are fluidly coupled together to enable mixing of the components provided through the ports  402 - 406 . The segment  418  is provided to couple the main bore  416  to a reducer  420  (having reducer opening  408 ) having the inverted diffuser sections. The reducer  420  may be further coupled to a through-bore  432  of smaller diameter than the main bore  416 . The reducer  420  is illustrated as part of the segment  418  that is separated from the wellhead body  414 , but that is integral to the wellhead body  414 . In an example, an additional flange may be provided between the segment  418  and the further through-bore  442  below the reducer.  FIG. 4  also illustrates that the sections  434 ,  436  are sufficiently dimensioned to be able to pass through the reducer opening  408  or through the main port  402  and bore  416  to the location in the reducer  420 , prior to being fastened or press-fitted in position. 
       FIG. 5A  illustrates different views of an inverted diffuser  500  having at least one releasable section  502 A-D,  504 A-D, in accordance with an aspect in the present disclosure.  FIG. 5A  illustrates a plan view and a cross-sectional view of an inverted diffuser that may be installed within the configuration of the wellhead  400  in  FIG. 4 . For instance, the inverted diffuser  500  has two vertical surfaces  506 ,  512 , and one main or prominent inclined surface  508  that is inclined in reference to one or more of the vertical surfaces  506 ,  512 . Furthermore, the first channels referred to in the embodiments of  FIGS. 2B, 3, and 4  are also illustrated in  FIG. 5A  via reference numerals  510 A-D. The first channels  510 A-D are illustrated as having threads to receive respective bolts that will then hold the respective channels in place against the wall of the wellhead.  FIG. 5A  also illustrates that there are four fastening sections  502 A-D (e.g., representing at least one first section in the embodiments of  FIGS. 2A, 3, and 4 ) and four press-fitted sections  504 A-D (e.g., representing at least one second section in the embodiments of  FIGS. 2A and 3 ). The dimensions for the sections are all so that a plan-view dimension enables fitting of the sections through a bore and through an opening of the segment holding the reducer. Further, the dimensions for the sections are so that they can be fitted together, either press-fitted or fastened without (or with insignificant) gaps there between. In an aspect, the gap between sections may be about 0.025 to 0.035 inches, which may be a byproduct of a cutting process (e.g., saw, or laser), when the sections are machined from a singular material. The cross-section dimensions provide at least a height of the inverted diffuser and a thickness of each of the sections. 
       FIG. 5B  illustrates a perspective view of sections  552 A-D,  554 A-D forming an inverted diffuser  550 , such as the inverted diffuser  500  of  FIG. 5A , in accordance with an aspect in the present disclosure. However, different than the inverted diffuser  500  of  FIG. 5A , the inverted diffuser  550  of  FIG. 5B  may be differently dimensioned or shaped so that the press-fit sections  554 A-D have a wide internal dimension distinct from the wedge-shaped internal feature illustrated in sections  504 A-D of  FIG. 5A . Nonetheless, the dimensions and shapes of the sections may be predetermined to provide a best combination of one or more of a combination of press-fit and fastened sections for the application. In the case of high pressure and high abrasive slurries, it might be the case that fastened sections are better suited, but for lower abrasive slurries, press-fit sections may be used adjacent to at least one fastened section. Furthermore, the first channels referred to in the embodiments of  FIGS. 2B, 3, and 4  are also illustrated in  FIG. 5B  via reference numerals  560 A-D. The first channels  560 A-D have threads, but may also include other releasable locking features, to receive respective bolts that will then hold the respective channels in place against the wall of the wellhead. Further, the press-fit sections  554 A-D are illustrated as having side surface  562 A,  562 B to engage with side surfaces (e.g., side surface  564 A or  564 B) of the fastened sections  552 A-D. 
       FIG. 6  illustrates plan views of different arrangements of sections  600  for inverted diffusers having at least two releasable sections, in accordance with aspects in the present disclosure. In at least one aspect, the arrangement of sections may include two first sections  602 A,  602 B forming the at least one first section that are fastened to the wall of a segment of a wellhead via fasteners in channels  606 A,  606 B; and two second sections  604 A,  604 B forming the at least one second section which are both press-fitted with the two first sections  602 A,  602 B. Alternatively, the arrangement of sections  600  may include two second sections  614 A,  614 B forming the at least one second section, and with the two second sections  614 A,  614 B being press-fitted with the at least one first section  612  that is fastened to the wall of the segment via a fastener at channel  616 . In a further alternative, the arrangement of sections  600  may include the at least one second section  604 A;  604 B;  614 A;  614 B that is adapted to be fastened to the wall along with, and located adjacent to, the at least one first section  602 A;  602 B;  612 . In yet another alternative arrangement of the section, two or three second sections  622 A-C;  632 A,  632 B with adaptations to be fastened via channels  626 A-C;  636 A,  636 B may be provided to form the at least one second section and to be fastened to the wall along with, and adjacent to, the at least one first section  622 D;  632 C that also has adaptations to be fastened via channels  626 D;  636 C. The channels are described and illustrated in the singular, but may be one or more channels in each section as illustrated in the cross-sectional and perspective views discussed throughout this disclosure. 
       FIG. 7  illustrates a process flow  700  of a method for application of an inverted diffuser that uses at least two releasable sections in a wellhead or other wellsite equipment, in accordance with an embodiment in the present disclosure. The method includes placing  702  a first one of the at least two releasable sections into the wellhead or the wellsite equipment. The at least two releasable sections have a first vertical inner surface and a first inclined inner surface relative to the first vertical inner surface. The method also includes placing  704  a second one of the at least two releasable sections into the wellhead or the wellsite equipment adjacent to the first one of the at least two releasable sections. Alignment of the first and the second ones of the at least two releasable sections may be verified in sub-process  706 . Placement may be repeated via at least sub-process  704  if required. The method further includes fastening  708  the first one of the at least two releasable sections to a wall of the wellhead using one or more releasable fasteners within one or more channels of the first one of the at least two releasable sections so that the at least two releasable sections are held in place against the wall of the wellhead or the wellsite equipment. 
       FIG. 8  illustrates a process flow  800  of a method for manufacturing an inverted diffuser having at least two releasable sections for use within a wellhead or other wellsite equipment, in accordance with an embodiment in the present disclosure. The method includes determining  802  dimensions of a segment of the wellhead that is adapted to include the inverted diffuser. A further step in the method is machining  804 , based at least in part on the dimensions, at least two releasable sections to include, on individual first sides of the at least two releasable sections, a vertical inner surface and a inclined inner surface relative to the vertical inner surface. Alignment of the at least two releasable sections may be verified in sub-process  806 . Machining may be repeated via at least sub-process  808  if required. The method includes drilling  808  one or more channels into an individual second side of at least one of the at least two releasable sections and threading  810  the one or more channels to receive one or more releasable fasteners. 
     From all the above, a person of ordinary skill would readily understand that the tool of the present disclosure provides numerous technical and commercial advantages, and can be used in a variety of applications. Various embodiments may be combined or modified based in part on the present disclosure, which is readily understood to support such combination and modifications to achieve the benefits described above.