An apparatus and method is provided for containing fluid or gas that is released when two adjoining sections of pipe are disconnected. The apparatus can comprise two or more arcuate sections hinged together to form a generally cylindrical or tubular containment chute that can be releasably enclosed around a pipe joint. Latching mechanisms can hold the apparatus around the pipe joint. The apparatus can have one or more sealing members at each end of the containment chute that engage the pipe above and below the pipe joint so that the pipe joint is completely enclosed and sealed off. A spout located on the sidewall of the apparatus allows fluid or gas that is released when the pipe joint is broken to flow from the apparatus through the spout into a hose connected to the spout, whereby the hose can divert the fluid or gas to a receptacle or container.

TECHNICAL FIELD 
       [0001]    The present disclosure is related to the field of mud cans, also known as “Kelly cans”, in particular, tubular enclosures for directing fluid or gas released when a threaded joint is disconnected between adjoining drilling pipe sections or between a Kelly and a pipe section. 
       BACKGROUND 
       [0002]    During the drilling of a well, drilling fluid is pumped down a hollow drill string and through the drill bit attached thereon. The drill string consists of a plurality of joined sections of pipe. The drilling fluid is pumped down the drill string using a device known as a “Kelly”. The Kelly is attached to the top of the drill string and is a connected to a source of pressurized drilling fluid via a hose. The Kelly is configured to allow the drill string to rotate when drilling the well while the hose remains generally stationary. Pressurized drilling fluid is, thus, pumped through Kelly into the drill string during drilling operations. 
         [0003]    The drilling fluid serves to carry cuttings produced by the drill bit to the surface in the space between the drill string and the walls of the well hole being drilled. This space is often referred to as the “annulus”. The drilling fluid also creates a hydrostatic pressure in the annulus that prevents produced substances from blowing out of the well. 
         [0004]    The process of removing the drill string from the well consists of raising the drill string out of the well and disconnecting one or more sections of joined pipe from the drill string. This process is often referred to as “tripping out”. Before the pipe sections are removed, the Kelly is removed from the drill string. A Kelly and its associated hose can contain approximately 20 gallons of drilling fluid that is under considerable pressure. The sections of pipe being tripped out also contain drilling fluid inside. When the Kelly or a pipe section is disconnected from the drill string, the drilling fluid in the Kelly or the pipe section spills out uncontrollably over the drilling rig floor and the personnel drilling the well. This results in an unsafe and hazardous environment for the personnel to work in. 
         [0005]    It is, therefore, desirable to provide an apparatus that prevents the spilling of drilling fluid on the drilling rig floor when the Kelly or when sections of pipe in a drill string are disconnected. 
       SUMMARY 
       [0006]    An apparatus and method for containing fluids or gas released from a pipe is provided. The apparatus can comprise two or more arcuate sections hinged together to form a generally cylindrical or tubular containment chute that can be releasably enclosed around a pipe joint. Latching mechanisms can be used to hold the apparatus around the pipe joint. The apparatus can have one or more sealing members at each end of the containment chute that engage the pipe above and below the pipe joint so that the pipe joint is completely enclosed and sealed off. The sealing members can be of different sizes to provided staged sealing about the pipe joint. A spout can be located on the sidewall of the apparatus that allows drilling fluid that is released when the pipe joint is broken to flow from the apparatus through the spout into a hose connected to the spout, whereby the hose can divert the drilling fluid to a receptacle for recycling and reuse. 
         [0007]    For the purposes of this specification and the claims contained herein, the term “rig” shall be deemed to include all forms of “rigs” known to those skilled in the oil and gas industry including “drilling rigs”, “test rigs”, “service rigs” and “off-shore rigs”. The term “pipe” shall be deemed to include “drill pipe”, “drill collars”, “tubulars”, “saver subs” or “thread-saver subassemblies”, “core barrels”, “top drive quills”, “coiled tubing”, “production tubing”, “down-hole assemblies”, “bottom-hole assemblies” and any other known tool or device having a threaded pipe joint connector that allows the connection to a pipe section containing fluid or gas. 
         [0008]    For the purposes of this specification and the claims contained herein, the term “pipe joint” shall refer to connections between the Kelly and a pipe section, and to connections between adjoining pipe sections. 
         [0009]    Broadly stated, an apparatus is provided for use in containing fluid or gas that is released upon disconnection of a threaded joint between sections of pipe or between a Kelly and a pipe section, the apparatus comprising: at least two arcuate sections of a generally tubular housing having upper and lower ends and outer and inner surfaces, the sections hinged together and configured to substantially enclose the threaded joint thereby providing a generally cylindrical enclosure disposed about the threaded joint; a handle disposed on at least one arcuate section; at least one upper groove disposed on the inner surface of the upper end of each arcuate section whereby at least one upper circumferential groove is formed on the inner surfaces when the arcuate sections are enclosed about the threaded joint; at least one lower groove disposed on the inner surface of the lower end of each arcuate section whereby at least one lower circumferential groove is formed on the inner surfaces when the arcuate sections are enclosed about the threaded joint; sealing means disposed in the at least one upper and lower circumferential grooves for providing a sealing contact with the Kelly or with the drilling pipe when the arcuate sections are enclosed about the threaded joint; latching means for releasably latching the arcuate sections together when the housing is enclosed about the threaded joint, the latching means comprising at least one latching mechanism; and a spout disposed on the outer surface of at least one arcuate section near the lower end and above the at least one lower groove, the spout configured to provide communication between the outer and inner surfaces thereby providing a path for drilling fluid to flow through when the arcuate sections are enclosed about the threaded joint and the threaded joint is disconnected. 
         [0010]    Broadly stated, a method is provided for containing fluid or gas that is released upon disconnection of a threaded joint between sections of pipe or between a Kelly and a pipe section, the method comprising the steps of: providing an apparatus, comprising: at least two arcuate sections of a generally tubular housing having upper and lower ends and outer and inner surfaces, the arcuate sections hinged together and configured to substantially enclose the threaded joint thereby providing a generally cylindrical enclosure disposed about the threaded joint, a handle disposed on at least one tubular housing section, at least one upper groove disposed on the inner surface of the upper end of each arcuate section whereby at least one upper circumferential groove is formed on the inner surfaces when the arcuate sections are enclosed about the threaded joint, at least one lower groove disposed on the inner surface of the lower end of each arcuate section whereby at least one lower circumferential groove is formed on the inner surfaces when the arcuate sections are enclosed about the threaded joint, sealing means disposed in the at least one upper and lower circumferential grooves for providing a sealing contact with the Kelly or with the drilling pipe when the sections are enclosed about the threaded joint, latching means for releasably latching the arcuate sections together when the arcuate sections are enclosed about the threaded joint, the latching means comprising at least one latching mechanism, and a spout disposed on the outer surface of at least one arcuate section near the lower end and above the at least one lower groove, the spout configured to provide communication between the outer and inner surfaces thereby providing a path for drilling fluid to flow through when the housing is enclosed about the threaded joint and the threaded joint is disconnected; placing the apparatus around the threaded joint, thereby enclosing the threaded joint; attaching one end of a hose to the spout, and placing the other end of the hose at a receptacle; and disconnecting the thread joint within the apparatus, whereby drilling fluid exiting from the Kelly from the drilling pipe section flows through from the apparatus through the spout and the hose to the receptacle. 
     
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
         [0011]      FIG. 1  is a front elevation view depicting a first embodiment of an apparatus for preventing the spilling of drilling fluid onto a drilling rig floor. 
           [0012]      FIG. 2  is a side elevation view depicting the apparatus of  FIG. 1 . 
           [0013]      FIG. 3  is a front elevation view depicting a second embodiment of an apparatus for preventing the spilling of drilling fluid onto a drilling rig floor. 
           [0014]      FIG. 4  is a side elevation view depicting the apparatus of  FIG. 3 . 
           [0015]      FIG. 5  is a top perspective view depicting the apparatus of  FIG. 3  in a closed position. 
           [0016]      FIG. 6  is a side perspective view depicting the apparatus of  FIG. 3  in a closed position with the latching mechanism being unlatched. 
           [0017]      FIG. 7  is a side elevation view depicting the apparatus of  FIG. 6 . 
           [0018]      FIG. 8  is a side perspective view depicting the apparatus of  FIG. 6  with the latching mechanism fully disengaged. 
           [0019]      FIG. 9  is a side perspective view depicting the outside of the apparatus of  FIG. 6  in an open position. 
           [0020]      FIG. 10  is a side elevation view depicting the inside of the apparatus of  FIG. 6  in an open position. 
           [0021]      FIG. 11  is a side perspective view depicting a second embodiment of a seal for use with the apparatus of  FIG. 1  or  3 . 
           [0022]      FIG. 12  is a side perspective view depicting the drain port of the apparatus of  FIG. 10 . 
           [0023]      FIG. 13  is a side perspective view depicting a first embodiment of a seal for use with the apparatus of  FIG. 1  or  3 . 
       
    
    
     DETAILED DESCRIPTION OF EMBODIMENTS 
       [0024]    An apparatus and method for preventing the spilling of drilling fluid onto a drilling rig floor is provided. Referring to  FIGS. 1 to 4 , two embodiments of a “Kelly kan” are shown as represented by apparatus  10 . In these embodiments, apparatus  10  can be configured as a tubular member formed by a plurality of arcuate sections that are hinged together to form a containment chute when enclosed about a Kelly or a tubing joint. In the illustrated embodiments, apparatus  10  can comprise arcuate sections  16  and  18  hinged together along one edge with hinge  14 . While representative embodiments comprise two arcuate or semi-circular sections, it is obvious to those skilled in the art that three or more hinged arcuate sections can be used to form apparatus  10 . Apparatus  10  can be comprised of any suitable material rated for use with produced substances, drilling fluids and muds, or fracturing fluids. In a representative embodiment, apparatus  10  can be comprised of high-density urethane polymer plastic to make apparatus  10  strong, lightweight and durable as well as being resilient to the fluids and gas that can come in contact with apparatus  10 . In other embodiments, apparatus  10  can be comprised of other materials having similar properties as well known to those skilled in the art. 
         [0025]    In operation, apparatus  10  can be opened by spreading sections  16  and  18  away from each other to allow apparatus  10  to be placed around a pipe joint. Sections  16  and  18  can then be pushed together to form the containment chute that completely encloses the pipe joint. Apparatus  10  can further comprise one or more handles  12  to allow personnel to manipulate apparatus  10  on and off pipe joints. In a further embodiment, handle  12  can comprise chamfered corners  13  as a safety feature to allow personnel place their thumbs on to avoid potential crush injuries from other equipment on the drilling rig floor such as the power tongs used to hold sections of pipe. 
         [0026]    In the illustrated embodiments, hinge  14  can comprise a “piano hinge” style of hinge although any suitable hinge can be used. In each of these illustrated embodiments, apparatus  10  can comprise a plurality of latch mechanisms  24  disposed in a spaced-apart configuration along one edge of apparatus  10  to releasably join sections  16  and  18  together.  FIGS. 1 and 2  illustrate an embodiment of apparatus  10  that is longer than the embodiment shown in  FIGS. 3 and 4 . In  FIG. 1 , apparatus  10  is shown comprising 5 latch mechanisms  24  whereas in  FIG. 3 , apparatus  10  is shown comprising 3 latch mechanisms  24 . It is obvious to those skilled in the art that the length of apparatus  10  and the number of latch mechanisms  24  can be selected as a design choice to build apparatus  10  to a desired length depending on the type and size of the Kelly or tubing joint to be enclosed by apparatus  10 . In further embodiments, apparatus  10  can comprise spout  20  disposed on a sidewall of apparatus  10 . Spout  20  provides communication to interior  11  of apparatus  10  to allow drilling fluid to exit from apparatus  10  through outlet  26  when the pipe joint is broken. In a representative embodiment, spout  20  can be disposed towards the lower end of apparatus  10  to minimize the amount of drilling fluid retained in apparatus  10  when enclosed around a pipe joint that is being broken. 
         [0027]    As shown in  FIGS. 1 to 4 , apparatus  10  can comprise a plurality of latch mechanisms to attach sections  16  and  18  together. In a further embodiment, the plurality of latch mechanisms  24  can be “ganged together” with latch handle  28  whereby all latch mechanisms  24  can be operated as a single group by using latch handle  28  to either open or close latch mechanisms  24 . 
         [0028]    Referring to  FIG. 5 , the top end of apparatus  10  is shown, with apparatus  10  in a closed position. In this figure, mating edges  30  of section  16  are in contact with mating edges  32  of section  18 . In one embodiment, mating edges  30  and  32  can comprise sealing profile  34 . In further embodiments, sealing profile  34  can comprise a tongue and groove profile that enables mating edges  30  and  32  to interlock with one another when apparatus  10  is enclosed about a pipe joint. Sealing profile  34  can act to prevent drilling fluids from escaping apparatus  10  along the edges of sections  16  and  18  when the pipe joint is broken. In a representative embodiment, sealing profile  34  can comprise two tongues and two grooves whereby each tongue and groove along mating edges  30  and  32  forms an individual seal line along the edges. With the double tongue and groove arrangement, two consecutive seal lines are formed along the mating edges when apparatus  10  is in a closed position. 
         [0029]    Referring to  FIGS. 6 to 8 , latch mechanisms  24  of apparatus  10  are depicted. In  FIG. 6 , latch mechanisms  24  are shown in a partially open position. In one embodiment, latch mechanism  24  can comprise an over-center style latch although any equivalent style of latch can be used as obvious to those skilled in the art. In the illustrated embodiment, each latch mechanism  24  can comprise latch hinge member  40  pivotally attached to section  16  that can further comprise hook member  36  pivotally attached to latch hinge member  40 . Hook member  36  is configured to engage catch member  38  disposed on section  18 . As shown, latch mechanisms  24  are ganged together by latch handle  28 . Moving latch handle  28  towards section  18  causes hook members  36  to engage catch members  38  until latch handle  28  reaches the over-center position thereby keeping latch mechanisms  24  in a fully latched position. Moving latch handle  28  away from section  18  releases hook members  36  from catch members  38  (as shown in  FIG. 7 ) thereby enabling apparatus  10  to be opened by moving sections  16  and  18  away from one another (as shown in  FIG. 8 ). 
         [0030]    Referring for  FIG. 9 , apparatus  10  is shown in an open position with spout  20  shown disposed on the outer surface of section  16 . In one embodiment, spout  20  can comprise a frustoconical or funnel shape culminating in outlet  26 . In a further embodiment, spout  20  can comprise circumferential groove  22  for providing means for coupling with a hose (not shown) that diverts drilling fluid off of the drilling rig floor to a holding tank (not shown). 
         [0031]    Referring to  FIG. 10 , apparatus  10  is shown in an open position displaying interior  11 . In one embodiment, upper seal grooves  42  can be disposed at the upper end of sections  16  and  18  within interior  11 . In another embodiment, lower seal grooves  43  can be disposed at the lower end of sections  16  and  18  within interior  11 . In a representative embodiment, sections  16  and  18  can comprise two upper seal grooves  42  and two lower seal grooves  43  although it is obvious to those skilled in the art that the number of seal grooves is a design choice, and that fewer or more seal grooves can be used depending on the size of the pipe, the pipe joint and the volume and pressure of drilling fluid released when the pipe joint is broken. For the purposes of this specification, the term “outer upper seal groove” shall refer to the upper seal groove  42  closest to the exterior of apparatus  10  whereas the term “inner upper seal groove” shall refer to the upper seal groove  42  closest to the interior of apparatus  10 . Similarly, the term “outer lower seal groove” shall refer to the lower seal groove  43  closest to the exterior of apparatus  10  whereas the term “inner lower seal groove” shall refer to the lower seal groove  43  closest to the interior of apparatus  10 . 
         [0032]    In one embodiment, seal grooves  42  and  43  can be configured with a T-shaped groove opening to receive a seal segment that can be slidably inserted and removed therefrom although any suitable groove shape can be used that can releasably retain a seal segment configured to inserted therein. Referring to  FIG. 11 , one embodiment of seal segment  44  is shown. In this embodiment, seal segment  44  can be comprised of an arcuate member made of elastomeric sealing material configured to be slidably inserted into upper seal groove  42  or lower seal groove  43 . Referring to  FIG. 12 , one embodiment of seal segment  46  is shown, also comprised of an arcuate member made of elastomeric sealing material configured to be slidably inserted into upper seal groove  42  or lower seal groove  43 . Seal segments  44  and  46  can be comprised of any suitable elastomeric material as well known by those skilled in the art that enable seal members  44  and  46  to flex, stretch and/or compress so as to maintain a sealing contact with the external surface of the pipe due to any irregularities to the cross-sectional shape of the pipe or to the contour of the pipe's external. Suitable examples of the elastomeric material for seal members  44  and  46  can include natural rubber, neoprene rubber, foam rubber, silicone-based rubber, nitrile rubber, foam plastic and any other material known to those skilled in the art that is suitable for use as a seal around a drill string. In a representative embodiment, seal segments  44  and  46  can be comprised of polyethylene cross-linked foam plastic. 
         [0033]    In one embodiment, seal segment  44  can comprise notches  50  on each end whereas seal segment  46  can comprise protrusions  54  configured to snugly insert into notches  50  when sections  16  and  18  are enclosed about a pipe joint thereby forming a continuous circular or toroidal seal around the pipe when apparatus  10  is fully enclosed around the pipe joint. 
         [0034]    In one embodiment, seal segment  44  can comprise grooves  52  disposed on the top and bottom surfaces thereof to provide means to enable seal segment  44  to be slidably inserted into T-shaped upper or lower seal grooves  42  and  43 . It is obvious to those skilled in the art that seal segments  44  or  46  can comprise other means besides grooves  52  to enable the seal segments to be releasably inserted in upper or lower seal grooves  42  and  43  if grooves  42  or  43  do not comprise a T-shaped opening. By providing seal segments of this configuration, worn or damaged seal segments can be easily replaced by drilling rig floor personnel without any special tools, skills or knowledge. 
         [0035]    Referring to  FIGS. 11 and 12 , each seal segment  44  and  46  comprises width W. Width W is selected as a design consideration in accordance with the diameter of pipe being used in the drilling operation. The width W of seal segments  44  and  46  is inversely proportional to the diameter of pipe or Kelly used. Width W can be selected to be narrower for larger diameter pipes, and wider for narrower diameter pipes. In another embodiment, apparatus  10  can be supplied as or with a kit having a plurality of seal segments  44  and  46  of varying widths W thereby enabling apparatus  10  to be used with pipes of various diameters. In a representative embodiment, apparatus  10  can be provided in a kit with a plurality of seal segments  44  and  46  where the segments are configured to be used with pipes whose diameter can range from 1 inch to 5 inch. 
         [0036]    In another embodiment, seal segments  44  and  46  of varying sizes can be used in a single apparatus  10 . In such configurations, apparatus  10  can be referred to as having “staged seals”. As an example, the upper and lower outer seal grooves can be fitted with seal segments that are wider than the seal segments fitted in the upper and lower inner seal grooves. By doing so, the outer seal segments can fit snugly around the pipe above and below the pipe joint whereas the inner seal segments can fit snugly around the pipe joint itself, which is larger in diameter than the pipe's diameter. 
         [0037]    In another embodiment, sections  16  and  18  can comprise two upper seal grooves  42  and two lower seal grooves  43  to enable the use of seal segments  44  and  46  that have differing properties. As an example, apparatus  10  can also be used as a pipe stripper and wiper where apparatus  10  is held stationary by personnel while the pipe is raised upwards through apparatus  10  by the drilling rig elevator. In this configuration, the outer and inner lower seal grooves can be fitted with seal segments that are dense and hard to compress, which make these seal segments better suited for scraping or stripping off larger or heavier solids attached from the exterior of the pipe. In addition, the outer and inner upper seal grooves can be fitted with seal segments that are less dense and easier to compress, which makes these seal segments better suited for wiping off residual fluids from the pipe's exterior and even compress enough to pass over the pipe joint as the drill string is raised up from the well. 
         [0038]    Referring to  FIG. 13 , apparatus  10  is shown in an open position, exposing interior  11  thereof, specifically, the interior side of section  16 . In this embodiment, spout opening  48  is shown and provides communication to spout outlet  26  of spout  20  as shown in  FIGS. 1 to 4 . In one embodiment, spout opening  48  can have a funnel shape that narrows in diameter towards spout outlet  26 . In another embodiment, spout opening  48  can have flat bottom surface  56  that can positioned to be substantially level with the top edge on the lower inner seal groove. In this configuration, the amount of residual drilling fluid that remains in apparatus  10  when drilling fluid is released within apparatus  10  upon breaking a pipe joint can be minimized. In applications where apparatus  10  is used to enclose a pipe joint on pipe being removed from a snubbing unit on a gas producing well, embodiments of apparatus  10  can be adapted to contain gas that is released when the pipe joint is disconnected or broken whereby the gas can exit apparatus  10  through spout  20  to a gas containment vessel (not shown) via a hose (not shown) connected to spout  20 . 
         [0039]    Although a few embodiments have been shown and described, it will be appreciated by those skilled in the art that various changes and modifications might be made without departing from the scope of the invention. The terms and expressions used in the preceding specification have been used herein as terms of description and not of limitation, and there is no intention in the use of such terms and expressions of excluding equivalents of the features shown and described or portions thereof, it being recognized that the scope of the invention is defined and limited only by the claims that follow.