Abstract:
A subsea connector assembly with flowmeter incorporated therein. The assembly is particularly configured for securing a flexible flowline at subsea production managing hardware such as at a manifold at a seabed or Christmas tree at a well head. Incorporating a flowmeter into the connector as opposed to such comparatively larger scale hardware ultimately saves substantial material, transport, installation, footspace and other costs.

Description:
CROSS REFERENCE TO RELATED APPLICATION(S) 
       [0001]    This Patent Document claims priority under 35 U.S.C. §119(e) to U.S. Provisional Application Ser. No. 62/334,870, entitled Connector with Monitor for Flexible Flowline, filed on May 11, 2016, which is incorporated herein by reference in its entirety. 
     
    
     BACKGROUND 
       [0002]    Exploring, drilling and completing hydrocarbon and other wells are generally complicated, time consuming and ultimately very expensive endeavors. As a result, over the years, well architecture has become more sophisticated where appropriate in order to help enhance access to underground hydrocarbon reserves. For example, as opposed to land based oilfields accommodating wells of limited depth, it is not uncommon to find offshore oilfields with wells exceeding tens of thousands of feet in depth. Furthermore, today&#39;s hydrocarbon wells often include a host of lateral legs and fractures which stem from the main wellbore of the well toward a hydrocarbon reservoir in the formation. 
         [0003]    In addition to the complexities of the field itself, the oilfield business itself may also be quite complex. For example, it is not uncommon for a variety of different wells at a given field to have multiple owners. This might include the circumstance where a single well is owned by multiple producers. Similarly, circumstances may involve several wells at an oilfield that are separately owned but which are produced to a single location and/or serviced by a single manifold such that the production from different wells is combined. 
         [0004]    Multiple producer ownership allows owners to share the expenses and risk of operations. However, the arrangement introduces accounting issues. For example, where ownership is different from one producing well to the next, there is a need to couple a flowmeter to each well at some location before the production fluids are combined and produced to surface. 
         [0005]    Conventionally, it makes sense to place a flowmeter assembly directly at the well, for example, by incorporating the flowmeter into standard Christmas tree hardware at the wellhead. The assembly may be added to the Christmas tree at surface before installation of the tree. However, for a cluster of wells, this requires that each Christmas tree of the cluster be outfitted with a substantial amount of added hardware. That is, in addition to the flowmeter itself, a sizeable landing structure is also required to accommodate the flowmeter. This usually translates into upwards of four cubic feet of volume and perhaps up to 1,000 lbs. or more being added to each tree. Thus, not only is the installation more challenging and time consuming but it is also much more costly. 
         [0006]    In an effort to reduce costs, flowmeter assemblies may be added to a manifold that services the same cluster of wells. In this way, the trees may be installed without concern over the added costs and challenges associated with supporting individual flowmeter assemblies. Instead, this issue is transferred over to a manifold. As a practical example, this means that rather than performing six different installations with flowmeter assembly challenges, a single manifold with six different dedicated flowmeter assemblies may be installed a single time. 
         [0007]    Unfortunately, while transferring the challenge from six trees to a single manifold may add some efficiencies, it does not actually remove the challenge altogether. Indeed, in certain respects, the challenge grows. Continuing with the example above, the challenge literally grows in terms of the sheer size increase of the manifold. Already a several thousand pound piece of equipment, the new manifold with integrated flowmeters has likely grown thousands more pounds and increased in size by 30-50%. This is because six different flowmeter assemblies, each about 4 cubic feet in size, have been added to the connection points on the manifold, one for fluid pairing to each well and tree. 
         [0008]    If operators are able to install such a manifold, it will save time spent on installation of the Christmas trees at the wellheads. However, the challenge of such a massive installation can be daunting. For example, the sheer size of the manifold may mean that only one manifold may be installed at a time at an oilfield due to the limitations on the capacity of available installation vessels. Once more, the installation time may also be increased. Ultimately, these factors may mean that days may be added to the complete installation time. This not only costs in terms of lost time, but it also means that installation vessel expenses, generally over $250,000 in today&#39;s dollars are driven up. 
         [0009]    As indicated, some efficiencies may be achieved through incorporating flowmeter assemblies on manifolds. However, as a practical matter, operators often opt to incorporate these assemblies on Christmas trees due to convention and to avoid the risks and challenges associated with incorporating flowmeter assemblies on manifolds. 
       SUMMARY 
       [0010]    A subsea connector assembly for use with a flexible flowline is described. The assembly includes a landing end for fluidly coupling to a subsea structure at the oilfield and receiving production therefrom. The connector also includes a termination end for coupling to the flexible flowline. A flowmeter is thus, fluidly coupled to each of the landing and termination ends to monitor the flow of production through the flowmeter. 
     
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
         [0011]      FIG. 1  is a perspective view of an embodiment of a flowmeter equipped subsea connector assembly. 
           [0012]      FIG. 2  is a side view of an installation vessel accommodating a host of flowmeter equipped subsea connector assemblies as depicted in  FIG. 1 . 
           [0013]      FIG. 3  is a perspective overview of a subsea oilfield accommodating embodiments of reduced profile manifolds and connector assemblies as depicted in  FIG. 2 . 
           [0014]      FIG. 4A  is a side view of an embodiment of a connector assembly with a separable joint. 
           [0015]      FIG. 4B  is a side view of a base of the connector assembly of  FIG. 4A  with a structural conduit removed therefrom at the joint. 
           [0016]      FIG. 4C  is a side view of an embodiment of a flowmeter incorporated into the subsea connector assembly of  FIG. 1 . 
           [0017]      FIG. 4D  is a side view of the flowmeter equipped subsea connector assembly of  FIG. 1 . 
           [0018]      FIG. 5  is a flow-chart summarizing an embodiment of assembling and employing an embodiment of a flowmeter equipped subsea connector assembly at a subsea oilfield. 
       
    
    
     DETAILED DESCRIPTION 
       [0019]    In the following description, numerous details are set forth to provide an understanding of the present disclosure. However, it will be understood by those skilled in the art that the embodiments described may be practiced without these particular details. Further, numerous variations or modifications may be employed which remain contemplated by the embodiments as specifically described. 
         [0020]    Embodiments are described with reference to certain subsea operations utilizing a flowmeter equipped connector assembly. For example, operations in which a cluster of wells at a seabed are each fluidly coupled to a dedicated flowmeter equipped connector assembly before production is combined at a manifold is described. In the embodiment shown, this takes place at a tree over each well with production advancing through a flexible flowline to the manifold. However, a variety of different layouts may take advantage of the unique connector assembly as detailed herein. For example, the connectors may be positioned at the manifold on the other end of the flowline or at various points in between. Indeed, so long as a unique connector of comparatively reduced profile is utilized to accommodate the flowmeter in place of incorporating the flowmeter with the underlying tree, manifold or other large scale equipment, appreciable benefit may be realized. 
         [0021]    Referring now to  FIG. 1 , a perspective view of an embodiment of a flowmeter equipped subsea connector assembly  100  is shown. The assembly  100  includes a standard base  175  for coupling to a subsea production related equipment such as a manifold ( 200 ,  250 ) or a Christmas tree ( 375 ,  377 ,  380 ,  390 ) (see  FIGS. 2 and 3 ). So, for example, a six inch diameter fluid coupling between the base  175  and a corresponding hub at such equipment may be present through which production flows into or out from the equipment. More specifically, with added reference to  FIG. 3  in particular, connector assemblies  100  are shown secured at landing hubs of the noted trees  375 ,  377 ,  380 ,  390 . Thus, production fluid from the trees  375 ,  377 ,  380 ,  390  is drawn into the connector assemblies  100  at the base  175  and ultimately directed toward corresponding manifolds  200 ,  250 . However, in other embodiments, these unique flowmeter equipped connector assemblies  100  may instead be fluidly coupled to landing hubs at the manifolds  200 ,  250 . In either case, the production fluid from any given well below a tree  375 ,  377 ,  380 ,  390  is afforded the opportunity to pass through a flowmeter  150  before mixing with any other production fluid from any other well. The flowmeter  150  may be single or multi-phase depending on the type of production expected. Additionally, the flowmeter  150  may be any of a number of different configurations suitable for subsea oilfield use such as gamma ray or venturi configurations. Further, the flowmeter may acquire more detailed fluid analysis in addition to establishing flow. For example, the flowmeter may include capacity to acquire temperature measurements, constitution measurements, consistency measurements, particulate measurements, and erosion measurements. 
         [0022]    Continuing with reference to  FIG. 1 , with added reference to  FIG. 3 , the flowmeter equipped connector assembly  100  is similar to other conventional connectors utilized to connect flexible jumpers or flowlines  300  to production equipment. Specifically, a gooseneck extension  110  with an induction bend is provided with a termination  125  for secure coupling to a flexible flowline  300 . However, instead of providing the extension  110  and termination  125  immediately over the base  175 , a host of intervening structure, most notably, a flowmeter  150  is provided. 
         [0023]    In the embodiment shown, base  140  and extension  130  flanges are provided for fluidly and securely connecting to lower  190  and upper  195  tubing hardware at either side of the noted flowmeter  150 . The insertion of this intervening structure has an affect on the architecture and overall profile of the assembly  100 . Therefore, in the embodiment shown, an added support  177  is provided for stabilizing the gooseneck extension  110  relative the base  175 . 
         [0024]    With added reference to  FIG. 4A , in absence of the flowmeter  150  and tubing hardware  190 ,  195  (and support  177 ), the flanges  130 ,  140  shown in  FIG. 1  may actually secure to one another at a connection joint  401 . Indeed, connector assemblies  100  may be provided with a connection joint  401  to operators along with separately provided flowmeters  150  and related hardware. In this way, operators may be afforded the opportunity to splice in a flowmeter  150  as depicted depending on the assembly&#39;s intended use depending on the oilfield layout and design as discussed further below. 
         [0025]    Referring now to  FIG. 2 , a side view of an installation vessel  275  is shown over a subsea oilfield  201 . The vessel  275  is shown accommodating a host of flowmeter equipped subsea connector assemblies  100  as depicted in  FIG. 1 . Perhaps more notably, the vessel  275  also accommodates multiple manifolds  200 ,  250 . Together, the assemblies  100  and manifolds  200 ,  250  take up between about half and two thirds of the footspace required for conventional flowmeter equipped manifolds (e.g. see  305  of  FIG. 3 ). 
         [0026]    The above described reduction in size for the manifolds  200 ,  250  is achieved due to the disassociation flowmeters from the large scale manifold hardware. This is because when a flowmeter is incorporated directly into the host production structure, such as a manifold or tree, the flowmeter requires correspondingly large scale piping, frame support and other matching hardware. However, with added reference to  FIG. 1 , where the flowmeter  150  is disassociated from such large scale equipment, its profile may be reduced. In fact, in the embodiments herein, the flowmeter  150  is not only disassociated from large scale equipment but it is incorporated into a comparatively small connector assembly  400  that would be utilized regardless (see  FIG. 4A ). That is, rather than disassociating the flowmeter  150  from large scale equipment and building an entirely new smaller equipment platform for the flowmeter  150 , a connector assembly  400  likely to be called for in operations already is uniquely re-configured to render the assembly  100  of  FIG. 1 . Due to the much smaller profile, large scale structural hardware additions are not required for this incorporation. Recall the upper  195  and lower  190  tubing hardware and support  177  of  FIG. 1  are substantially sufficient to support the complete incorporation of the flowmeter  150 . 
         [0027]    Continuing with reference to  FIG. 2 , the added footspace available on the installation vessel  275  due to the reduction in manifold size may save a tremendous amount of time and expense. For example, even setting aside the reduction in hardware costs, more manifolds  200 ,  250  may be accommodated. Thus, fewer trips to the oilfield  201  may be necessary. Further, manifold deployment from a crane  225  to the seabed, as depicted in  FIG. 3 , may take less time due to the reduction in manifold weight. All told, in today&#39;s dollars, the disassociation of the flowmeter  150  of  FIG. 1  from large scale production equipment may result in hundreds of thousands in savings. 
         [0028]    Referring now to  FIG. 3 , a perspective overview of the layout for the subsea oilfield  201  referenced above is shown. In this particular layout, multiple well clusters  325 ,  335  are coupled to manifolds  200 ,  250  via connector assemblies  100 . This exemplary oilfield  201  includes a conventional offshore platform  360  from which subsea operations may be directed. In this particular example, bundled water and production lines  340  and bundled electrical/hydraulic lines  310  may run along the seabed between the platform  360  and the cluster locations. 
         [0029]    The oilfield  201  accommodates embodiments of the reduced profile manifolds  200 ,  250  and connector assemblies  100  as depicted in  FIG. 2 . More specifically, a connector assembly  100  is fluidly secured at every tree for every individual well at two different well clusters  325 ,  335 . Recalling that each assembly  100  is outfitted with a flowmeter  150 , this means that production flow from each individual well and tree (e.g.  375 ,  377 ,  380 ,  390 ) may be monitored before being combined at a manifold (e.g.  200  or  250 ) and then further combined at production lines  340  on the way to surface. 
         [0030]    As a practical matter, this type of arrangement means that the production from each well may be tracked individually. This may be of benefit to operators monitoring production, for example, to track and make adjustments to operations where appropriate on a well by well basis. This also provides benefit where the wells are of differing ownership. That is, where collected production at the surface is to be allocated to different owners of different wells, it may be important to know, from an accounting perspective, which wells produced which amount of the production. Once more, this is achieved without the requirement of substantially enlarging the size of the trees (e.g.  375 ,  377 ,  380 ,  390 ) or the manifolds (e.g.  200  or  250 ) to accommodate incorporated flowmeters. 
         [0031]    Continuing with reference to  FIG. 3 , previously installed, more conventional manifolds  305 ,  307  with incorporated flowmeters are also shown at the oilfield  201 . With added reference to  FIG. 2 , it is unlikely that these manifolds  305 ,  307  were able to be accommodated at the installation vessel  275  simultaneously. As a result, multiple trips to the oilfield  201  and longer installation times for each manifold  305 ,  307  were the likely result. The same type of increased size and profile issues would result if the flowmeters were instead incorporated into conventional trees. However, by associating flowmeters (e.g.  150  of  FIG. 1 ) with flexible line connector assemblies  100 , such large scale profile and weight issues may be addressed through a type of equipment likely to be employed at the oilfield  201  anyway. That is, where flexible line  300  is to be used between trees  375 ,  377 ,  380 ,  390  and manifolds  200 ,  250 , some form of connector will be utilized even in absence of flowmetering. Thus, unique benefit is realized in reconfiguring this particular equipment into such a small scale assembly  100  (also see  FIG. 1 ). 
         [0032]    It is worth noting that the assembly  100  is depicted at the trees  375 ,  377 ,  380 ,  390  in the embodiment shown. However, in other embodiments, the flowmeter equipped connector assembly  100  may instead be secured at the other end of the flexible line  300  (e.g. at the manifold  200 ,  250 ). By the same token, the assemblies  100  may work effectively through either vertical or horizontal connection. Furthermore, in other embodiments utilizing a different layout, the assemblies  100  may be secured to a hub at a pipeline, a pipeline end termination (PLET), a pipeline end manifold (PLEM) or other suitable subsea or even surface production equipment structure. So long as flowmetering is able to intervene through a connector  100  in advance of combining production from differing wells, appreciable benefit may be realized. 
         [0033]    Referring now to  FIG. 4A , a side view of an embodiment of a connector assembly  400  is shown with a separable joint  401 . This connector assembly  400  may be provided standard. For example, in the embodiment of  FIG. 3  where the flowmeter equipped connector assembly  100  is utilized at Christmas trees  375 ,  377 ,  380 ,  390 , the connector assembly  400  of  FIG. 4A  may be utilized at the manifolds  200 ,  250 . Of course, as described below, this same assembly  400  may be reconfigured into the assembly  100  of  FIG. 1 . 
         [0034]    Referring now to  FIG. 4B , a side view of a lower portion  425  of the connector assembly of  FIG. 4A  is shown with the gooseneck extension  110  removed from the base  175  at the joint  401 . Specifically, the base flange  140  is separated from the extension flange  130  and exposed for being fluidly coupled to other equipment. Specifically, as shown in  FIG. 4C , a side view of an embodiment of a flowmeter  150  is shown with lower  190  and upper  195  tubing hardware for incorporation into the assembly  100  of  FIG. 4D . As indicated above, the flowmeter  150  may be of a gamma ray, venturi or other suitable type. Additionally, the flowmeter  150  may constitute housing substantial enough to include added processing capability for the production fluid. For example, the housing may include any of a pump, a process fluid turbine, a gas injection apparatus, a steam injection apparatus, a chemical injection apparatus, a chemical treatment apparatus, a pressure boosting apparatus, a water electrolysis apparatus, a materials injection apparatus, a gas separation apparatus, a water separation apparatus, a sand/debris separation apparatus and a hydrocarbon separation apparatus. 
         [0035]    Referring now to  FIG. 4D , a side view of the fully assembled flowmeter equipped subsea connector assembly  100  of  FIG. 1  is shown. The flowmeter  150  has been secured to the base flange  140  of  FIG. 4B  via the lower tubing hardware  190 . Similarly, the gooseneck extension  110  has been secured at the upper tubing hardware  195  and a structural support  177  has been added between the base  175  and the extension  110  to complete the assembly  100 . 
         [0036]    Referring now to  FIG. 5 , a flow-chart is shown summarizing an embodiment of assembling and employing a flowmeter equipped subsea connector assembly at a subsea oilfield. Specifically, once the connector is equipped with a flowmeter as indicated at  520 , it may be fluidly coupled to a subsea structure for managing production fluid as indicated at  540 . So, for example, even before manifold or tree structures are deployed from an installation vessel, the assemblies may be manually coupled to the structures at a time of greater manual access. The structure may then be installed at the seabed (see  560 ). Of course, this may not always be called for or even possible, for example where the structure has already been installed and flowmeter capacity is sought at a later time, in which case, the addition of the flowmeter equipped connector may take place subsea (see  540 ). 
         [0037]    Whatever the sequence of installation, the use of the flowmeter equipped connector allows for the monitoring of production through the structure as noted at  580 . More specifically, this monitoring takes place on a well by well or well specific basis prior to the combining of the production with production from any other well. Thus, in addition to efficiencies detailed hereinabove a reliable manner of production accounting takes place for each specific well. 
         [0038]    Embodiments described above provide a new and unique form of subsea hardware that disassociates flowmeter functionality from large scale equipment that manages well production on a well by well or well specific basis. This allows for flowmeter functionality without dramatically increasing the size of manifolds, Christmas trees and other such equipment to accommodate a flowmeter. Thus, dramatic savings may be realized in equipment expenses as well as costs in terms of installation time. 
         [0039]    The preceding description has been presented with reference to presently preferred embodiments. Persons skilled in the art and technology to which these embodiments pertain will appreciate that alterations and changes in the described structures and methods of operation may be practiced without meaningfully departing from the principle, and scope of these embodiments. Furthermore, the foregoing description should not be read as pertaining only to the precise structures described and shown in the accompanying drawings, but rather should be read as consistent with and as support for the following claims, which are to have their fullest and fairest scope.