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CROSS-REFERENCE TO RELATED APPLICATIONS 
       [0001]    This application claims the benefit of U.S. Provisional Application No. 60/804,789, filed 25 Mar. 2013. The entirety of this aforementioned application is incorporated herein by reference. 
     
    
     TECHNICAL FIELD OF THE INVENTION 
       [0002]    This invention relates, in general, to a system and method for removing debris from a downhole wellbore. 
       BACKGROUND OF THE INVENTION 
       [0003]    Without limiting the scope of the present invention, its background will be described in relation to a system and method for removing debris from a downhole wellbore, as an example. 
         [0004]    Recovering hydrocarbon gas from downhole environments can be problematic. For example, in coal seam gas recovery operations, water in the wellbores oftentimes impedes the gas recovery process in a particular hydrocarbon bearing formation. In some gas recovery or production processes, one or more horizontally drilled wellbores are intersected or connected with one or more vertical wellbores that contain pumps for removing the water that collects in the wellbore system. After the water is removed through the vertical wellbores, then hydrocarbon gas can be recovered through the same vertical wellbores, for example. 
         [0005]    One problem associated with the de-watering process is that it creates a low bottom hole pressure in the downhole wellbore that causes fines and debris, drawn with the hydrocarbon gas, to accumulate in the horizontal wellbore. Eventually, the horizontal wellbore accumulate enough fines or debris to severally restrict or block the flow of the hydrocarbon gas into the vertical wellbores causing a reduction in gas production. At this point, the fines or debris must be removed from the wellbore to restore the flow of hydrocarbon gas. Similarly, fines and/or debris may restrict or block the flow of hydrocarbon gas through the vertical wellbores, which then may also need to be removed to restore production gas flows. 
       SUMMARY OF THE INVENTION 
       [0006]    The present invention disclosed herein is directed to a system and method for removing debris from a downhole wellbore (“downhole debris removal system”). In one embodiment, the present invention is directed to a downhole debris removal tool, including a mandrel having an upper end and a lower end and a central passageway extending therebetween; a screen basket having an upper end and a lower end, the screen basket slidably disposed about the mandrel and operatable between an open position and a closed position; and a nose member having an upper end and a lower end and located substantially proximal to and in fluid communication with the lower end of the mandrel, the lower end of the nose member having one or more outlets for providing a stream of fluid therethrough. 
         [0007]    In one aspect, the lower end of the screen basket may include a flared end for sealing with the upper end of the nose member when in the closed position. Additionally, the upper end of the screen basket may be in a sealed arrangement with the mandrel for creating an annular space between the inner surface of the screen basket and the outer surface of the mandrel for retaining fines and debris. Further, the upper end of the nose member may terminate in an angular shoulder for sealing with the flared end of the lower end of the screen basket. 
         [0008]    In another aspect, the screen basket may include a plurality of screen openings sized to allow fluid to pass through while retaining fines and debris. Also, the flared end may be a gage ring. The downhole debris removal tool may also include an upper sub connected to the upper end of the mandrel, the upper sub having a larger diameter than the mandrel for engaging with the upper end of the screen basket when in the open position. 
         [0009]    In another embodiment, the present invention may be directed to a method for removing fines and debris from a downhole wellbore in a formation, including introducing a tubing string having a downhole debris removal tool disposed substantially near the lower end of the tubing string into the downhole wellbore; positioning the downhole debris removal tool substantially proximal to the fines and debris; circulating fluid through the downhole debris removal tool for disintegrating the fines and debris; and collecting the fines and debris in the downhole debris removal tool for removal out of the downhole wellbore. 
         [0010]    In one aspect, the disintegrating the fines and debris may include flowing a fluid under pressure through one or more outlets disposed through the end of the downhole debris removal tool. Also, the collecting the fines and debris may include filtering the fines and debris from the fluid through screens disposed about the downhole debris removal tool. Further, the method may include advancing distally the tubing string into the downhole wellbore. 
         [0011]    In another aspect, the introducing a tubing string having a downhole debris removal tool may further include flowing a fluid under pressure through one or more outlets disposed through the end of the downhole debris removal tool. Additionally, the positioning the downhole debris removal tool may include reversing direction of travel of the tubing string to create a larger distance between the downhole debris removal tool and the fines and debris. In yet another aspect, the collecting the fines and debris in the downhole debris removal tool may further include slidably closing the downhole debris removal tool to contain the fines and debris within the downhole debris removal tool. 
         [0012]    In yet another embodiment, the present invention may be directed to a method for recovering hydrocarbon gas from a downhole wellbore in a formation, including providing one or more substantially lateral wellbores and one or more substantially vertical wellbores in fluid communication with one another in the formation; introducing a submersible pump into one or more of the one or more vertical wellbores; extracting water from the downhole wellbore through one or more of the substantially vertical wellbores; extracting the hydrocarbon gas from the downhole wellbore through one or more of the one or more substantially lateral wellbores and the one or more substantially vertical wellbores; introducing a tubing string having a downhole debris removal tool disposed substantially near the lower end of the tubing string into the downhole wellbore; positioning the downhole debris removal tool substantially proximal to a blockage of fines and debris; circulating fluid through the downhole debris removal tool for disintegrating the blockage of fines and debris; and collecting the fines and debris in the downhole debris removal tool for removal out of the downhole wellbore. 
         [0013]    In one aspect, the method may further include removing the downhole debris removal tool from the downhole wellbore. Also, the method may further include resuming the extraction of the hydrocarbon gas from the downhole wellbore through one or more of the one or more substantially lateral wellbores and the one or more substantially vertical wellbores. In another aspect, the disintegrating the blockage may include flowing a fluid under pressure through one or more outlets disposed through the end of the downhole debris removal tool. 
         [0014]    In yet another aspect, the collecting the fines and debris may include filtering the fines and debris from the fluid through screens disposed about the downhole debris removal tool. Further, the positioning the downhole debris removal tool may include reversing direction of travel of the tubing string to create a larger distance between the downhole debris removal tool and the fines and debris. Additionally, the collecting the fines and debris in the downhole debris removal tool may include slidably closing the downhole debris removal tool to contain the fines and debris within the downhole debris removal tool. 
         [0015]    In still yet another embodiment, the present invention may be directed to a a method for recovering hydrocarbon gas from a coal seam gas well, including providing one or more substantially lateral wellbores and one or more substantially vertical wellbores in fluid communication with one another in a coal seam; introducing a submersible pump into one or more of the one or more vertical wellbores; extracting water from the downhole wellbore through one or more of the substantially vertical wellbores; running a tubing string having a downhole debris removal tool disposed substantially near the lower end of the tubing string into one or more of the one or more substantially lateral wellbores; circulating fluid through the downhole debris removal tool for disintegrating a mass of coal fines; collecting the coal fines in the downhole debris removal tool for removal out of the coal seam gas well; removing the downhole debris removal tool from the coal seam gas well; and extracting the hydrocarbon gas from the coal seam gas well through one or more of the one or more substantially lateral wellbores and the one or more substantially vertical wellbores. 
         [0016]    In one aspect, the running a tubing string may further include running a second tubing string having a downhole debris removal tool disposed substantially near the lower end of the second tubing string into one or more of the one or more substantially vertical wellbores. Also, the method may further include moving distally the downhole debris removal tool further into the coal seam gas well. In another aspect, the disintegrating a mass of coal fines may include flowing a fluid under pressure through one or more outlets disposed through the end of the downhole debris removal tool. Additionally, the collecting the fines and debris may include filtering the fines and debris from the fluid through screens disposed about the downhole debris removal tool. 
         [0017]    In yet another aspect, the positioning the downhole debris removal tool may further include reversing direction of travel of the tubing string to create a larger distance between the downhole debris removal tool and the fines and debris. Further, the collecting the fines and debris in the downhole debris removal tool may further include slidably closing the downhole debris removal tool to contain the fines and debris within the downhole debris removal tool. 
     
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
         [0018]    For a more complete understanding of the features and advantages of the present invention, reference is now made to the detailed description of the invention along with the accompanying figures in which corresponding numerals in the different figures refer to corresponding parts and in which: 
           [0019]      FIG. 1  is a schematic illustration of a downhole debris removal system according to an embodiment; 
           [0020]      FIG. 2  is a schematic illustration of a downhole debris removal system according to another embodiment; 
           [0021]      FIG. 3A  is a cross-section view of a downhole debris removal tool in a first operating position of the downhole debris removal system according to an embodiment; 
           [0022]      FIG. 3B  is a cross-section view of a downhole debris removal tool in a second operating position of the downhole debris removal system according to an embodiment; 
           [0023]      FIG. 3C  is a side view of a downhole debris removal tool of the downhole debris removal system according to an embodiment; 
           [0024]      FIG. 4  is a flowchart of a process for removing fines and debris from a downhole wellbore of the downhole debris removal system according to an embodiment; 
           [0025]      FIG. 5  is a flowchart of a process for removing fines and debris from a downhole wellbore of the downhole debris removal system according to another embodiment; and 
           [0026]      FIG. 6  is a flowchart of a process for removing coal fines from a downhole wellbore in a coal seam of the downhole debris removal system according to another embodiment. 
       
    
    
     DETAILED DESCRIPTION OF THE INVENTION 
       [0027]    While the making and using of various embodiments of the present invention are discussed in detail below, it should be appreciated that the present invention provides many applicable inventive concepts which can be embodied in a wide variety of specific contexts. The specific embodiments discussed herein are merely illustrative of specific ways to make and use the invention, and do not limit the scope of the present invention. 
         [0028]    In the following description of the representative embodiments of the invention, directional terms, such as “above,” “below,” “upper,” “lower,” etc., are used for convenience in referring to the accompanying drawings. In general, “above,” “upper,” “upward,” and similar terms refer to a direction toward the earth&#39;s surface along a wellbore, and “below,” “lower,” “downward,” and similar terms refer to a direction away from the earth&#39;s surface along the wellbore. Additionally, the term “proximal” refers to a linear, non-linear, or curvilinear distance or point nearer to a point of reference or direction that is closer to a relative term or object, and the term “distal” refers to a linear, non-linear, or curvilinear distance or point farther to a point of reference or direction that is farther to a relative term or object. 
         [0029]    Referring to  FIG. 1 , a downhole debris removal system in use with an oil and gas production unit is schematically illustrated and generally designated  50 . One or more water onshore extraction control units  52   a - 52   n  (collectively water extraction control units  52 ) are located over an oil and gas formation  54 . Although downhole debris removal system  50  is discussed herein with reference to onshore production, downhole debris removal system  50  may be used with any type of onshore or offshore oil and/or gas rig and/or operation as are commonly known to those skilled in the art. A wellhead installation  56  may include a blowout preventer  58 , which may be located on ground  60  for providing fluid communication and control between formation  54  and oil and gas operations, such as a coiled tubing unit (not shown), for example. As is known to those skilled in the art, wellhead installation  56  and blowout preventer  58  are part of many different configurations of oil and gas rigs, platforms, operations, and the like, and that other components that may be commonly associated with processing and recovering hydrocarbon gases and fluids for consumer use are not shown or described herein. Further, downhole debris removal system  50  may be used with other types of hydrocarbon recovery operations that are commonly known to those skilled in the art. 
         [0030]    In another embodiment, other types of surface control units other than wellhead installation  56  and blowout preventers  58  may be used with downhole debris removal system  50 . For example, a coiled tubing unit may be in place of wellhead installation  56  and blowout preventers  58 . 
         [0031]    A wellbore  62  extends through the various earth strata including formation  54 . A casing  64  may be cemented within a vertical and/or horizontal section of wellbore  62  by cement  66 . Even though  FIG. 1  depicts one lateral wellbore  62 , it should be understood by those skilled in the art that downhole debris removal system  50  may be used in conjunction with any number of vertical and/or lateral wellbores. Additionally, wellbore  62  may be a cased or open hole wellbore in fluid communication with one or more vertical wellbores, as described further below. 
         [0032]    Downhole debris removal system  50  may include a conduit  68 , such as coiled tubing or tubular members, which provide fluid communication to the downhole end of wellbore  62 . Some examples of conduit  68  may include casing, liners, and the like. Additionally, downhole debris removal system  50  may include one or more vertical wellbores  70   a - 70   n  (collectively vertical wellbores  70 ) that are in fluid communication with wellbore  62 . 
         [0033]      FIG. 1  shows a substantially cased wellbore  62  where conduit  68  extends substantially towards the end of wellbore  62 . In this embodiment, conduit  68  may include perforations, screens, and the like for allowing gas and liquids to pass from formation  54  into conduit  68 . Additionally in this embodiment, wellbore  62  may be partially or fully cemented. As shown in  FIG. 1 , cement  66  is not in place throughout the entire length of wellbore  62 . 
         [0034]    In another embodiment, wellbore  62  may be an open hole wellbore  62  where conduit  68  is not in place the entire length of wellbore  62 . In this embodiment, conduit  68  may extend a partial length through wellbore  62 , but may end prior to vertical wellbores  70 . In yet another embodiment, conduit  68  may extend any length through wellbore  62 . 
         [0035]    In addition, even though  FIG. 1  depicts downhole debris removal system  50  in a substantially horizontal wellbore, it should be understood by those skilled in the art that downhole debris removal system  50  is equally well suited for use in wells having other directional configurations including horizontal wells, vertical wells, deviated wellbores, slanted wells, multilateral wells, and the like. 
         [0036]    Although three substantially vertical wellbores  70  are shown in  FIG. 1 , any number of vertical wellbores  70  may be included with the present downhole debris removal system. Vertical wellbores  70  and wellbore  62  may all be in fluid communication with each other and may constitute a well system, in one embodiment. 
         [0037]    Downhole debris removal system  50  may further include one or more conduits  72   a - 72   n  (collectively conduits  72 ) in fluid communication with one or more pumps  74   a - 74   n  (collectively pumps  74 ) for extracting water and other fluids from any portions, including vertical, horizontal, lateral, and the like, of wellbore  62  as described further below. As shown in  FIG. 1 , conduit  72   a  is located in vertical wellbore  70   a , conduit  72   b  is located in vertical wellbore  70   b , and conduit  72   c  is located in vertical wellbore  70   c . As discussed above, any number of vertical wellbores  70  may be used with downhole debris removal system  50 . Additionally, in some instances, downhole debris removal system  50  may be used in a wellbore system that includes wellbore  62  but does not include vertical wellbores  70 . In yet another embodiment, downhole debris removal system  50  may be used in a wellbore system that includes vertical wellbores  70  but does not include wellbore  62 . Conduits  72  may be any type of tubular members, pipes, etc. that provide a pathway/flowpath between pumps  74  and water extraction control units  52  for gases, liquids, and fluids as are commonly known to those skilled in the art. 
         [0038]    Further, downhole debris removal system  50  may include a downhole debris removal tool  76  for removing fines and debris from any portions of wellbore  62 , in one embodiment. As shown in  FIG. 1 , downhole debris removal tool  76  is located substantially between vertical wellbore  70   b  and vertical wellbore  70   n  for clearing fines and debris in this section of wellbore  62 , in one example. Further, downhole debris removal tool  76  may be moved along and through any section of wellbore  62 , such as from any vertical wellbores  70  to any other vertical wellbores  70  as desired for selectively removing fines and debris disposed or accumulated in any portions of wellbore  62 , in one embodiment. 
         [0039]    As shown in  FIG. 1 , downhole debris removal system  50  may include one or more wellbores  62  for extracting hydrocarbon gas, water, and other gases and fluids. In addition, this wellbore may be used to extract or remove fines and debris with downhole debris removal tool  76  when parts of the well system become blocked or restricted by accumulated fines and debris in the well system. Additionally, wellbores  70   a - 70   n  may be used for extracting or removing water for de-watering the well system and they may also be used for recovering hydrocarbon gas from formation  54  once a desirable amount of water has been removed from the well system. In another embodiment, other components may be used in vertical wellbores  70  for de-watering the well system and recovering/controlling the recovery of hydrocarbons, such as hydrocarbon liquid and/or gas, that are commonly known to those skilled in the art. 
         [0040]    Turning now to  FIG. 2 , a downhole debris removal system in use with two oil and gas production units are schematically illustrated and generally designated  100 . In describing downhole debris removal system  100  many of the corresponding numerals shown refer to corresponding elements, parts, and the like described relative to downhole debris removal system  50 , thus they may not be repeated in detail below. As shown in  FIG. 2 , downhole debris removal system  100  further includes another oil and gas production unit including blowout preventer  102  and wellhead installation  104  for recovering oil and gas from a substantially vertical wellbore, such as vertical wellbore  70   a.    
         [0041]    Wellhead installation  56 , including blowout preventer  58 , are located on ground  60  for providing fluid communication and control between formation  54  and oil and gas operations, such as a coiled tubing unit (not shown), for example. As is known to those skilled in the art, wellhead installation  56  and blowout preventer  58  may be part of many different configurations of oil and gas rigs, platforms, operations, and the like, and that other components that may be commonly associated with processing hydrocarbon gases and fluids are not shown or described herein. 
         [0042]    Wellbore  70   a  extends through the various earth strata including formation  54 . Even though  FIG. 2  depicts one substantially lateral wellbore  62  and one substantially vertical wellbore  70   a  for recovering hydrocarbon gases and fluids it should be understood by those skilled in the art that downhole debris removal system  100  may be used in conjunction with any number of wellbores, such as lateral wellbore  62 . Further, downhole debris removal system  100  may be used with any number of substantially horizontal wellbores and vertical wellbores of a wellbore system. Additionally, wellbores  62  and  70   a  may be cased or open hole wellbores in fluid communication with one or more vertical wellbores, as described further herein. 
         [0043]    In addition, even though  FIG. 2  depicts downhole debris removal system  100  with a substantially vertical wellbore it should be understood by those skilled in the art that the downhole debris removal system is equally well suited for use in wells or well systems having other directional configurations including horizontal wells, vertical wells, deviated wellbores, slanted wells, multilateral wells and the like. 
         [0044]    Downhole debris removal system  100  may include a conduit  106 , such as coiled tubing, tubular members, pipe, and the like which provide fluid communication to the downhole end of wellbore  70   a . Additionally, downhole debris removal system  100  may include one or more vertical wellbores  70   b - 70   n  (collectively vertical wellbores  70 ) that are in fluid communication with wellbores  62  and  70   a . Although three vertical wellbores  70   a - 70   n  are shown in  FIG. 2 , any number of vertical wellbores  70  may be included with the present downhole debris removal system. Vertical wellbores  70  and wellbore  62  may all be in fluid communication with each other and may constitute a well system, in one embodiment. 
         [0045]    Conduit  106  is in fluid communication with formation  54  for extracting hydrocarbon gas and other fluids from any portions, including vertical, horizontal, lateral, and the like, of formation  54  as described further below. Further, downhole debris removal system  100  may include a downhole debris removal tool  76  located within vertical wellbore  70   a  for removing fines and debris from any portions of wellbore  70   a , in one embodiment. As can be seen in  FIG. 2 , downhole debris removal tool  76  is also located with wellbore  62 . 
         [0046]    As shown in  FIG. 2 , downhole debris removal system  100  may include one or more wellbores  62  and  70   a  for extracting hydrocarbon gas, water, and other gases and fluids. In addition, these wellbores may be used to extract or remove fines and debris with downhole debris removal tool  76  when parts of the well system become blocked or restricted by accumulated fines and debris in the well system. Additionally, wellbores  70   b - 70   n  may be used for extracting or removing water for de-watering the well system and they may also be used for recovering hydrocarbon gas from formation  54  once a desirable amount of water has been removed from the well system. 
         [0047]    Downhole debris removal systems  50 ,  100  may include any number of downhole debris removal tools  76  for removing accumulated fines and debris within any of the wellbores of the well or well system. In addition, several downhole debris removal tool  76  may be used in series or in a stacked configuration in each of one or more wellbore  62  and vertical wellbores  70 . For example, a series of downhole debris removal tool  76  may be located one above another along a work string and the like for utilizing in a downhole well environment. 
         [0048]    Referring now to  FIGS. 3A-3C , one embodiment of downhole debris removal tool  76  is shown. Downhole debris removal tool  76  includes a substantially tubular upper end  302  and upper sub  304  having a substantially tubular axially threaded end or connector  306  for coupling to a lower end of a tubular member or conduits  68  and  106  located above upper sub  304 . Downhole debris removal tool further includes a lower end  308 . Lower end  308  preferably is adapted to engage a collection of sand or other mass of fines and debris within formation  54  and/or the well system. In one embodiment, lower end  308  may be beveled or conical in shape for improved removal or engagement with fines and debris in formation  54  and/or well system. Lower end  308  also should be adapted or configured to provide a stream of fluid therethrough and thus, like upper end  302 , may also be substantially tubular. 
         [0049]    Most preferably, lower end  308  forms a nose cone or member  310  with one or more fluid nozzles, outlets, or jets sized and positioned to provide multiple jets of fluid at the leading end of nose member  310 . For example, nose member  310  may have a first outlet  312  along the longitudinal axis (LA) of downhole debris removal tool  76 . Additionally, nose member  310  also may have one or more angled nozzles, outlets, or jets  314  that are angled relative to LA, for example. 
         [0050]    Extending between upper end  302  and the lower end  308  of downhole debris removal tool  76  is a substantially tubular member, such as mandrel  316 . In one embodiment, the upper end of nose member  310  may be threadedly connected to the lower end of mandrel  316  via threaded ends or connectors  317 , while the lower end of upper sub  304  may be threadedly connected to the upper end of mandrel  316  via threaded ends or connectors  305 . These threaded connections may be provided with or include seals, such as O-rings (not shown). Still further, mandrel  316  may be integrally formed with the upper sub  304 , nose member  310 , or both. Additionally, mandrel  316  may consists of one member or may be one or more members that provide a flow path between upper sub  304  and nose member  310 . Thus, the lumens, passageways, or flowpaths of the upper sub  304 , mandrel  316 , and nose member  310  are continuous and form a flow passageway  318  extending end-to-end through the downhole debris removal tool  76 . 
         [0051]    A strainer or screen basket  320  is slidably supported on mandrel  316  substantially between upper sub  304  and nose member  310 . In one embodiment, an annular flowpath or space  325  is provided between the inner surface of screen basket  320  and the outer surface of mandrel  316  for providing a flowpath for the recovered fluids and fines from wellbore  62  and vertical wellbores  70 . While the structure and shape of screen basket  320  may vary, in a preferred form, screen basket  320  includes a tubular body  322  having multiple screen openings  324 , which are disposed through and about tubular body  322 . In one embodiment, screen basket  320  may be made from screen type materials that provide fluid flow therethrough while retaining fines and debris. 
         [0052]    Additionally, the diameter or size of screen openings  324  may be determined based on the size of fines and debris that are to be recovered from wellbore  62  and vertical wellbores  70 . The size of screen openings  324  should be such that the fines and debris recovered by downhole debris removal tool  76  in wellbore  62  and vertical wellbores  70  are trapped in space  325  of downhole debris removal tool  76  while providing for the flow of fluid through screen openings  324  of downhole debris removal tool  76  as discussed further below. 
         [0053]    The upper end of tubular body  322  may include an upper end member  326  that is slidably disposed about mandrel  316 . Upper end member  326  preferably may have a sloped exterior wall  328  on its upper or uphole end. The lower or downhole end of tubular body  322  is open for providing an opening or entrance to space  325  for enabling the flow of fines, debris, and fluid to flow into space  325  as discussed further below. In this particular embodiment, the lower or downhole end of tubular body  322  may include a gage ring  330  with a flared inlet  332 . Gage ring  330  may be connected to the end of tubular body  322  by a threaded coupler  334 . 
         [0054]    In another embodiment, in place of gage ring  330 , a belled or flared end may be formed to the lower end of tubular body  322 . The upper end of nose member  310  preferably has an angled annular shoulder  336  to facilitate a sealing engagement with inlet  332  of gage ring  330  of screen basket  320  when downhole debris removal tool  76  is in a substantially closed position as best shown in  FIG. 3B . 
         [0055]    Now it will be understood that as the tubing string, such as conduit  68 , is advanced into any of wellbores  62  and  70 , screen basket  320  will be urged upwardly on mandrel  316  allowing fines and debris carried in the well fluids to enter inlet  332  as shown by flowpath  327 . Screen openings  324  of screen basket  320  trap the fines and debris substantially within space  325  while allowing well fluid to flow through screen openings  324  by flowpath  329 . When the tubing string is withdrawn from the well system, screen basket  320  will be urged downwardly on the mandrel  316  until the flared inlet  332  abuts shoulder  336  and closes screen basket  320  thus trapping the fines and debris within space  325  of downhole debris removal tool  76 . This allows the collected fines and debris to be removed from the well system and pulled up to the surface. 
         [0056]    Downhole debris removal system  50  and downhole debris removal system  100  may also include methods of extracting fines and debris from one or more well systems in formation  54 , for example. With reference to  FIG. 4 , an embodiment of a method for removing fines and debris from a well and/or well system in formation  54  is schematically and generally designated  400 . In step  402 , downhole debris removal tool  76  may be attached to the end of one or more conduits and/or tubing strings, such as conduit  68  and conduits  72 , to be run into formation  54 . In step  404 , the conduit and/or tubing string including downhole debris removal tool  76  may then be introduced into formation  54  and advanced in a conventional manner. 
         [0057]    In step  406 , while the tubing string is advanced into one or more of wellbore  62  and/or vertical wellbores  70 , fluid may be circulated down through the tubing string through passageway  318  in downhole debris removal tool  76  and out the end of one or more outlets outlet  312 ,  314 . This flow will agitate the well fluids and assist in the flow of fluid, fines, and debris into inlet  332  of gage ring  330 . This is shown via flowpath  327  entering inlet  332 , where fines, debris, and fluid enter space  325 . Fines and debris are then screened or trapped within space  325  while fluid is allowed to pass through screen openings  324  shown via flowpath  329 . Fluid flow through downhole debris removal tool  76  may be continuous or intermittent. 
         [0058]    In step  408 , if a mass of fines, coal fines, sand, or other debris restricts or blocks the downhole wellbore, advancement of the tubing string may be halted while the fluid flow through downhole debris removal tool  76  is continued. Additionally, the tubing string may even be withdrawn slightly during this step to further facilitate the breaking up and removal of such a blockage. This step will allow one or more of outlet  312  and outlets  314  to force jet streams of fluid on the obstruction until it is broken and dislodged. This step may also include allowing fluid flow to be increased to facilitate the disintegration of the plug or obstruction, if necessary. In step  410 , advancement of the tool string may be resumed until the operation is completed. 
         [0059]    Now it will be appreciated that this method provides removal of fines and debris from a downhole wellbore in a formation, such as formation  54 . Downhole debris removal tool  76  enables continuous fluid flow while the drill string is advanced to agitate well fluids and debris, enhancing the operation of the tool and reducing the likelihood that operation will be interrupted by blockages of sand and debris in the well. 
         [0060]    With reference now to  FIG. 5 , another embodiment of a method for removing fines and debris from a well and/or well system in formation  54  is schematically and generally designated  500 . In this embodiment, one or more substantially lateral wellbores, such as wellbore  62  may be intersected with one or more substantially vertical wellbores  70 . In this embodiment, wellbore  62  and vertical wellbores  70  may be cased or open hole wellbores as commonly known to those skilled in the art. 
         [0061]    In step  502 , water may be first extracted from vertical wellbores  70  via conduits  72 , pumps  74 , and water extraction control units  52 . This dewatering step may occur through any or all of vertical wellbores  70 , for example. This step may include operating one or more water extraction control units  52  for controlling the flow of water through pumps  74  and conduits  72  to dewater the downhole wellbore or well system formed by the intersection of the substantially lateral section of wellbore  62  and vertical wellbores  70 . In step  504 , hydrocarbon gas may be recovered or extracted from one or more of wellbore  62  and vertical wellbores  70 . This step may include additional processing of the hydrocarbon gas subsequent to recovering it above ground  60 , for example. 
         [0062]    Once fines and debris begin to accumulate in the downhole wellbore in formation  54 , the flow of hydrocarbon gas may become restricted or blocked fully thereby reducing or stopping production of the hydrocarbon gas above ground  60 . In step  506 , downhole debris removal tool  76  may be run into the downhole well or well system and positioned substantially adjacent or proximal to the restriction or blockage. In step  508 , fluid may be circulated down through the tubing string through passageway  318  in downhole debris removal tool  76  and out the end of outlets  312  and  314 . This flow will agitate the well fluids and assist in the flow of fines, debris, and fluid through into inlet  332  as shown in flowpath  327  and into space  325 . Fines and debris will be screened or trapped within space  325  while fluid flow will occur through screen openings  324  as shown in flowpath  329 . Fluid flow through downhole debris removal tool  76  may be continuous or intermittent. 
         [0063]    In step  510 , if a mass of fines, coal fines, sand, or other debris restricts or blocks the downhole wellbore, advancement of the tubing string may be halted while the fluid flow through downhole debris removal tool  76  is continued. Additionally, the tubing string may even be withdrawn slightly during this step to further facilitate the breaking up and removal of such a blockage. This step will allow one or more of outlet  312  and outlets  314  to force jet streams of fluid on the obstruction until it is broken and dislodged. This step may also include allowing fluid flow to be increased to facilitate the disintegration of the plug or obstruction, if necessary. In step  512 , advancement of the tool string may be resumed until the operation is completed. 
         [0064]    In step  514 , downhole debris removal tool  76  may be removed from the downhole wellbore or well system. In step  516 , recovery or extraction of the hydrocarbon gas may be resumed through one or more of wellbore  62  and vertical wellbores  70  as described herein. This step may include recovering and further processing the hydrocarbon gas above ground  60  via one or more of wellbore  62  and vertical wellbores  70 , in one example. 
         [0065]    Now it will be appreciated that that this method provides removal of fines and debris from a downhole wellbore in a formation, such as formation  54 . Downhole debris removal tool  76  enables continuous fluid flow while the drill string is advanced to agitate well fluids and debris, enhancing the operation of the tool and reducing the likelihood that operation will be interrupted by blockages of fines, sand, and debris in the well. 
         [0066]    With reference now to  FIG. 6 , an embodiment of a method for removing coal fines from a well and/or well system in formation  54  is schematically and generally designated  600 . This particular embodiment may be applicable for coal seam gas wells, in one example. In this embodiment, one or more substantially lateral wellbores, such as wellbore  62  is intersected with one or more substantially vertical wellbores  70 . In this embodiment, wellbore  62  and vertical wellbores  70  may be cased or open hole wellbores as commonly known to those skilled in the art. In this embodiment, formation  54  may be a coal seam as is commonly known to those skilled in the art. 
         [0067]    In step  602 , submersible pumps  74  are run into or positioned in one or more vertical wellbores  70  and operated to extract water from the downhole wellbore or well system via conduits  72  and water extraction control units  52 , for example. As the water is pulled into the substantially lateral section of wellbore  62 , coal fines begin to accumulate and restrict one or more of wellbore  62  and vertical wellbores  70 . Due to the low bottom hole pressure, the coal fines are difficult to circulate out of the substantially lateral section of wellbore  62  and/or lower sections of vertical wellbores  70  and they accumulate creating blockages within one or more of wellbore  62  and vertical wellbores  70 , for example. 
         [0068]    In step  604 , downhole debris removal tool  76  may be run into the downhole well or well system and positioned substantially adjacent or proximal to the restriction or blockage caused by the accumulation of the coal fines. In steps  606  and  608 , fluid may be circulated down through the tubing string to passageway  318  in downhole debris removal tool  76  and out the end of one or more outlets outlet  312 ,  314 . This flow will agitate the well fluids and assist in the flow of fluid, fines, and debris into inlet  332  of gage ring  330 . This is shown via flowpath  327  entering inlet  332 , where fines, debris, and fluid enter space  325 . Fines and debris are then screened or trapped within space  325  while fluid is allowed to pass through screen openings  324  shown via flowpath  329 . Fluid flow through downhole debris removal tool  76  may be continuous or intermittent. 
         [0069]    Additionally regarding step  608 , if a mass of coal fines restricts or blocks the downhole wellbore, advancement of the tubing string may be halted in any of the wellbores while the fluid flow is continued, and the tubing string may even be withdrawn slightly. This step provides for a forceful stream of fluid to exit one or more outlet  312  and outlets  314  to work on the obstruction of coal fines until it is broken and dislodged. This step may also include allowing fluid flow to be increased to facilitate the disintegration of the plug or obstruction, if necessary. This step may further include capturing the coal fines in one or more downhole debris removal tool  76 . This step further includes having a pore size or screen mesh size of screen basket  320  to retain or collect the coal fines while simultaneously allowing fluid to pass through screen openings  324  of screen basket  320 . In step  610 , advancement of the tool string may be resumed until the operation is completed. 
         [0070]    In step  612 , downhole debris removal tool  76  may be removed from the downhole wellbore or well system. In step  614 , recovery or extraction of the hydrocarbon gas may begin through one or more of wellbore  62  and vertical wellbores  70  as described herein. This step may include recovering and further processing the hydrocarbon gas above ground  60  via one or more of wellbore  62  and vertical wellbores  70 , in one example. 
         [0071]    Now it will be appreciated that that this method provides removal of fines and debris from a downhole wellbore in a formation, such as formation  54 . Downhole debris removal tool  76  enables continuous fluid flow while the drill string is advanced to agitate well fluids and debris, enhancing the operation of the tool and reducing the likelihood that operation will be interrupted by blockages of fines, sand, and debris in the well. 
         [0072]    While this invention has been described with reference to illustrative embodiments, this description is not intended to be construed in a limiting sense. Various modifications and combinations of the illustrative embodiments as well as other embodiments of the invention will be apparent to persons skilled in the art upon reference to the description. It is, therefore, intended that the appended claims encompass any such modifications or embodiments.

Summary:
A method for removing fines and debris from a downhole wellbore in a formation, including introducing a tubing string having a downhole debris removal tool disposed substantially near the lower end of the tubing string into the downhole wellbore; positioning the downhole debris removal tool substantially proximal to the fines and debris; circulating fluid through the downhole debris removal tool for disintegrating the fines and debris; and collecting the fines and debris in the downhole debris removal tool for removal out of the downhole wellbore.