Abstract:
A completion tubular is placed in position adjacent the zone or zones to be fractured and produced. It features preferably sliding sleeve valves that can assume at least two configurations: wide open and open with a screen material juxtaposed in the flow passage. In a preferred embodiment the valve assembly has three positions, adding a fully closed position to the other two mentioned. After run in, the valves can be put in the wide open position in any order desired to fracture. After fracturing, the valves can be closed or selectively be put in filtration position for production from the fractured zones in any desired order. Various ways are described to actuate the valves. The tubular can have telescoping pistons through which the fracturing can take place if the application calls for a cemented tubular.

Description:
CROSS REFERENCE TO RELATED APPLICATION 
     This application is a divisional of U.S. patent application Ser. No. 13/015,323 filed Jan. 27, 2011, which was a divisional of U.S. patent application Ser. No. 11/840,011 filed Aug. 16, 2007, now U.S. Pat. No. 7,971,646. 
    
    
     FIELD OF THE INVENTION 
     The field of the invention relates to completion techniques involving fracturing and more particularly the ability to fracture discrete segments of a formation in a desired order through valved ports which can then be configured for sand control duty to let production begin without using a crossover tool and a separate run for sand control screens after the fracturing operation 
     BACKGROUND OF THE INVENTION 
     Typical completion sequences in the past involve running in an assembly of screens with a crossover tool and an isolation packer above the crossover tool. The crossover tool has a squeeze position where it eliminates a return path to allow fluid pumped down a work string and through the packer to cross over to the annulus outside the screen sections and into the formation through, for example, a cemented and perforated casing. Alternatively, the casing could have telescoping members that are extendable into the formation and the tubular from which they extend could be cemented or not cemented. The fracture fluid, in any event, would go into the annular space outside the screens and get squeezed into the formation that is isolated by the packer above the crossover tool and another downhole packer or the bottom of the hole. When a particular portion of a zone was fractured in this manner the crossover tool would be repositioned to allow a return path, usually through the annular space above the isolation packer and outside the work string so that a gravel packing operation could then begin. In the gravel packing operation, the gravel exits the crossover tool to the annular space outside the screens. Carrier fluid goes through the screens and back into the crossover tool to get through the packer above and into the annular space outside the work string and back to the surface. 
     This entire procedure is repeated if another zone in the well needs to be fractured and gravel packed before it can be produced. Once a given zone was gravel packed, the production string is tagged into the packer and the zone is produced. 
     There are many issues with this technique and foremost among them is the rig time for running in the hole and conducting the discrete operations. Other issues relate to the erosive qualities of the gravel slurry during deposition of gravel in the gravel packing procedure. Portions of the crossover tool could wear away during the fracking operation or the subsequent gravel packing operation. If more than a single zone needs to be fractured and gravel packed, it means additional trips in the hole with more screens coupled to a crossover tool and an isolation packer and a repeating of the process. The order of operations using this technique was generally limited to working the hole from the bottom up. 
     What the present invention addresses are ways to optimize the operation to reduce rig time and enhance the choices available for the sequence of locations where fracturing can occur. Furthermore, through a unique multi-position valve system, fracturing can occur in a plurality of zones in any desired order followed by reconfiguring the valve system to place filter media in position so that production could commence with a production string without having to run screens or a crossover tool into the well. These and other advantages of the present invention will be more readily apparent to those skilled in the art from the description of the various embodiments that are discussed below along with their associated drawings, while recognizing that the claims define the full scope of the invention. 
     SUMMARY OF THE INVENTION 
     A completion tubular is placed in position adjacent the zone or zones to be fractured and produced. It features preferably sliding sleeve valves that can assume at least two configurations: wide open and open with a screen material juxtaposed in the flow passage. In a preferred embodiment the valve assembly has three positions, adding a fully closed position to the other two mentioned. After run in, the valves can be put in the wide open position in any order desired to fracture. After fracturing, the valves can be closed or selectively be put in filtration position for production from the fractured zones in any desired order. Various ways are described to actuate the valves. The tubular can have telescoping pistons through which the fracturing can take place if the application calls for a cemented tubular. Alternatively, the tubular can be in open hole and simply have openings for passage of fracture fluid and external isolators to allow fracturing in any desired order. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
         FIG. 1  is a half section view showing three position valves in the open position for run in with the optional telescoping passages retracted; 
         FIG. 2  is the view of  FIG. 1  with the tubular cemented and the telescoping passages extended but still blocked off; 
         FIG. 3  is the view of  FIG. 2  with the upper valve closed and the lower valve open with the passage through the lower telescoping passage open and ready for fracturing; 
         FIG. 4  is the view of  FIG. 3  with the fracturing completed through the lower telescoping passage and the upper valve opened for fracturing through the upper telescoping passage; 
         FIG. 5  is the view of  FIG. 4  with fracturing complete through the upper telescoping passage; 
         FIG. 6  is the view of  FIG. 5  with both valves put in screening position; 
         FIG. 7  is a close up view of a three position valve in the closed position; 
         FIG. 8  is the view of  FIG. 7  with the valve in the wide open fracturing position; 
         FIG. 9  is the view of  FIG. 8  with the travel stops for the sliding sleeve shifted right; 
         FIG. 10  is the view of  FIG. 9  with the sleeve shifted against a relocated travel stop to the filtration position; 
         FIG. 11  is a section view of a j-slot guided version of the three position valve in the wide open position for fracturing; 
         FIG. 12  is the view of  FIG. 11  with the valve in the closed position; 
         FIG. 13  is the view of  FIG. 12  with the valve in the filtration position; 
         FIG. 14  is one possible j-slot layout to achieve the three positions shown in  FIGS. 11-13 ; 
         FIG. 15  is an alternative j-slot to the one in  FIG. 14  to achieve the three positions shown in  FIGS. 11-13 ; 
         FIG. 16  is a detailed view of a sliding sleeve design that operates on pressure differential between an annulus around a tubing string and pressure inside it; 
         FIG. 17  is the overall view of a three position valve in the closed position showing the indexing device for the three positions; 
         FIG. 18  is the view of  FIG. 17  with the valve in the filtration position; 
         FIG. 19  is the view of  FIG. 18  with the valve in the wide open position; 
         FIG. 20  is an alternative pressure based way of moving the multi-position valve shown in a position for pushing the piston downhole; 
         FIG. 21  is the view of  FIG. 19  in a position to push the piston uphole; 
         FIG. 22  is the view of  FIG. 20  in a neutral position where pressure does not cause movement; 
         FIG. 23  shows an open hole before insertion of the tubular for a completion; 
         FIG. 24  is the view of  FIG. 23  with the completion assembly supported from cemented casing and the multi-position valves closed; 
         FIG. 25  is the view of  FIG. 24  with the external packer set; 
         FIG. 26  is the view of  FIG. 25  with the lower valve open in a fracturing mode; 
         FIG. 27  is the view of  FIG. 26  with the string picked up and ready to open the upper valve for fracturing; 
         FIG. 28  is the view of  FIG. 27  with fracturing complete; 
         FIG. 29  is the view of  FIG. 28  with the string lowered in preparation for putting both valves in filtration mode; 
         FIG. 30  is the view of  FIG. 29  with the string removed and both valves shifted to filtration mode; 
         FIG. 31  is a schematic view of an alternative embodiment using discrete ports in the tubular for fracturing and filtering showing the closed ports position; 
         FIG. 32  is the view of  FIG. 31  with the fracture ports open; and 
         FIG. 33  is the view of  FIG. 32  with the filtering ports open. 
     
    
    
     DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENT 
     One way to illustrate the method of the present invention is to refer to  FIG. 1 . Wellbore  10  has a casing  12  that is cemented  14 . A work string  16  suspends a tubular string  18  that has an external liner hanger/seal  20 , shown in a set position to support string  18  from casing  12 . Illustratively, string  18  is shown with upper ports  22  and lower ports  24 . While only a single port  22  or  24  is shown, those skilled in the art will understand that the drawing is schematic and each hole represents multiple openings arranged in any order desired to meet the flow requirements. In this embodiment of the method, each opening  22  and  24  has a telescoping assembly  26  and  28  respectively that are shown in a retracted position for run in. Assemblies  26  and  28  could also be within string  18  for run in. Assemblies  26  and  28  respectively have passages  30  and  32  which are initially respectively blocked by rupture discs  34  and  36 . Openings  22  and  24  respectively have a valve assembly  38  and  40  located nearby in tubular  18 . In the variation shown in  FIG. 1 , valve assemblies have a clear port  42  and  44  and a filtration port  46  and  48 . They also have a long blank section  50  and  52 . The way valve assemblies  38  and  40  operate will be explored in detail later. At this point, referring to assembly  38  but covering however many assemblies like it are used, those skilled in the art can see that there will be a corresponding number of ports  42  or  46  for each port  22 . The filtration material in port  46  is preferably a sintered metal but other filtration materials can be used such as mesh screens. The assembly  38  is shown as a three position valve but it can be also be a two position valve that only presents either opening  42  or  46  aligned with port  22 . In that configuration, there is no closing the valve assembly  38 . 
       FIG. 2  shows the assemblies  26  and  28  extended and the tubular  18  cemented with cement  54 . These two steps can be in either order. Nothing else has changed. 
       FIG. 3  shows a work string  56  lowered into position and ready to break rupture disc  36  to fracture through assembly  28 . 
     In  FIG. 4  the rupture disc  36  is broken and proppant slurry  58  is pumped under pressure into the formation  60  through assembly  28  via aligned ports  44  and  24 . Pressure is maintained until flow drops off indicating the fracture through assemblies  28  is complete. 
     In  FIG. 5  the work string  56  is raised up in preparation for fracturing through assemblies  26  by breaking rupture disc  34  and delivering proppant or sand slurry  62  into formation  64 . Prior to delivering proppant or sand slurry  62  the use of a fluid loss control device such as a fluid loss control pill or another mechanism common to the art may be employed. 
     It should be noted that the projection  66  on work string  56  is intended to be a schematic representation of one of many ways to shift the valve assemblies  38  and  40  the details of at least some shifting alternatives will be described in more detail below.  FIG. 6  illustrates the valve assemblies  38  and  40  shifted up to align respectively port  46  with  22  and port  48  with  24 . At this point, a production string can be inserted and the formations  60  or/and  64  can be produced in any desired order or two or more formations at once. Those skilled in the art can appreciate that there can be additional arrays of ports beyond  22  and  24  and they can be aligned with a single producing zone or multiple zones. If there are multiple zones such as  60  and  64  they can be fractured in any desired order or together. Once a zone is fractured through a given array of ports such as  24 , those ports can be selectively isolated by juxtaposing blank portion  52  by port  24  for example. 
     It should also be noted that the use of assemblies  26  and  28  is optional and an open hole method will now be described by first referring to  FIG. 23 .  FIG. 23  shows a wellbore  70  that is an open hole at its lower end  72 . Casing  74  is cemented with cement  76 . In  FIG. 24  a running string  78  carries in a tubular string  80  until it can be secured to casing  74  with a hanger/packer  82 . As before, the string  80  has for example two arrays of ports  84  and  86 . Each array represents the needed number of openings properly sized and in any desired pattern. Each array of ports  84  and  86  has an associated valve member  88  and  90  respectively. Preferably each valve member has two hole arrays to match the patterns of ports  84  and  86 . In valve member  88  that would be arrays  92  and  94  and in valve member  90  it would be arrays  96  and  98 . Arrays  92  and  96  are open ports while arrays  94  and  98  have preferably a sintered metal filtration media but other types of screen materials such as wire mesh could also be used. In the  FIG. 24  position there is no array alignment with ports  84  or  86  rendering those ports closed. Optionally there can be no closed position and in that case for a given array of ports such as  84  for example, there will either be alignment with array  92  or  94 . In either variations of the method being described the valve assemblies need not all be identical. Some can be two position with no closed position and others can be three position with a closed, fracture and screen positions, as required. The actual operation of valve assemblies  88  or  90  will be discussed below. An external packer  100  is shown in the run in position. It can be one of a variety of packer styles and can be set by swelling or by expansion of string  80  with an adjustable swage, for example that can be run in through the work string  78  past valve assembly  88  to expand string  80  from inside in the region of the external packer  100 . Other packer types are also envisioned. 
     In  FIG. 25 , the packer  100  is set to isolate portion  102  from portion  104  of the wellbore  70 . Ports  84  and  86  are both closed. 
     In  FIG. 26  a work string  106  with a schematically illustrated shifter  108  is run into the wellbore  70  to put the array of openings  96  into alignment with matching array  86  so that segment  104  can be fractured. Openings  84  are still closed. 
       FIG. 27  shows the portion  104  of the wellbore  70  fully fractured and the string  106  repositioned and ready to align array  92  with array  84 . In  FIG. 28 , the frac job for portion  102  of the wellbore  70  uphole of packer  100  has been fractured. The work string  106  has shifted up and is in position to be further manipulated to reposition valve assemblies  88  and  90  into a filtration position. 
       FIG. 29  shows the work string repositioned prior to movement of valve assemblies  88  and  90 . In  FIG. 30  the work string  106  is removed and arrays  94  and  98  are respectively aligned with arrays  84  and  86 . The wellbore  70  can now go into production when a production string and a packer are set into position in string  80 . 
     To reduce trips in the wellbore  70  the string  78  that delivers the tubing string  80  can also do duty as a shifting device taking away any need to run a separate string  106  with a shifting device  108  on its lower end. Furthermore, the same string that delivers string  80  can also shift valve assemblies  88  and  90  as described and ultimately with a proper external packer (not shown) can also serve as the production string after the valve assemblies  88  and  90  are in the filtration mode shown in  FIG. 30 . 
     The advantage of the method shown in  FIGS. 24-30  is that screens and a crossover tool need not be run at all. The fracturing job can be done in any sequence desired by moving valves in the right order and setting external packers to isolate ports such as  84  and  86  in the open hole using a packer such as  100  between pairs of hole arrays. From fracturing the well can go right to production through the filter media in the arrays such as  94  and  98  when aligned with respective arrays  84  and  86 . Removing the crossover tool reduces risks of its failure from erosion or from getting stuck and not assuming the squeeze and then the circulation positions it must be put into to do fracturing followed by gravel packing. The elimination of the gravel packing also removes risks of bridging during gravel packing or complex structures such as bypass tubes in the annulus to get around sand bridges that form during gravel packing. Countless hours of rig time are saved as well as equipment charges to the well operator. 
     Even with the method of  FIGS. 1-6  which already had the advantage of eliminating the need to perforate by using assemblies  26  and  28 , there is an added advantage from the present method in that production can begin after fracturing by a simple repositioning of valves such as  38  and  40  to the filtration position by aligning ports  46  and  48  respectively with ports  22  and  24 . There is no need for a separate trip with screens and a crossover tool and the risks involved using such equipment, as described above. Apart from those benefits are the ability to fracture in any desired order and the ability to produce from any one or more of a desired number of downhole locations. If a certain zone starts to produce water, for example, it can be closed off. If such features are not needed the system can be even more simple using two position valves that allow fracturing or filtration with no closure option. Valve assemblies such as  38  and  40  can be arranged for individual operation or for tandem operation, as needed. They can be locally actuated through a work string  56  with a shifting tool  101  or they can be locally powered or powered by applied pressure, pressure differential, locally mounted and powered motors or other ways. 
     Different ways to operate the multi-position sliding sleeve valves of the preferred embodiment will now be described.  FIG. 7  shows the movable sleeve  110  disposed in a recess  112  whose ends are defined by movable travel stops  114  and  116 . Lower end  118  is against stop  116  in  FIG. 7  and that puts both ports  120  that is unobstructed and ports  122  that have a filtration media preferably sintered metal  124  out of alignment with ports  126  of the tubular  128 . This defines the closed position because a blank wall straddles seals  130  and  132  mounted to the tubular  128 .  FIG. 8  shows the sleeve  110  shifted so that upper end  134  is against stop  114  to get ports  120  into alignment with ports  126  to define the fracturing position. Those skilled in the art will appreciate that a known shifting tool (not shown) can grab sleeve  110  at grooves  136  or  138  and move sleeve  110  in opposed directions for closing ports  126 , as shown in  FIG. 7 , or putting them in a fully open and unobstructed position for fracturing, as shown in  FIG. 8 . It should be noted that with the stops  114  and  116  in the  FIGS. 7 and 8  positions the ports  122  cannot be put into alignment with ports  126 . 
     Stops  114  and  116  are rotatably mounted using threads  140  and  142  respectively. Stops  114  and  116  have a series of recesses schematically illustrated as  144  and  146  that allow a tool (not shown) to be run in and make contact there to rotate stops  114  and  116  about their respective threads  140  or  142  for repositioning of one or both stops as needed. In  FIG. 9  both stops  114  and  116  have been shifted right or downhole. Sleeve  110  has moved in tandem with stop  140  but ports  126  are still closed.  FIG. 10  shows sleeve  110  shifted with a tool (not shown) that attached at groove  138 . As a result of movement to the right or downhole of sleeve  110  the ports  122  and their filter material  124  are now aligned with ports  126 . In the  FIG. 10  position for the stops  114  and  116  the only positions possible are ports  126  closed, as in  FIG. 9  or ports  126  open for filtration, as in  FIG. 10 . Those skilled in the art will appreciate that only one stop between  114  and  116  could be moved. While rotating a thread to move the stops longitudinally is illustrated, those skilled in the art will appreciate that the stops can be translated longitudinally and moved by a locally applied mechanical force or a remotely or locally applied pressure force or other techniques that result in longitudinal movement of the stops  114  and  116 . Alternatively, stops  114  and  116  could be eliminated and sleeve  110  can be secured in recess  112  by a thread so that rotating it advances it longitudinally or sleeve  110  can be connected by a rack and pinion and driven longitudinally in opposed directions by a locally mounted motor or a driving force provided from a running tool, hydrostatic pressure or applied pressure in the wellbore, to name a few examples. Sleeve  110  can be made in pieces that move relative to each other so that instead of moving the travel stops  114  or  116  one portion of the sleeve  110  can be moved with respect to another to reposition the sleeve or openings thereon to achieve the same choice of positions for ports  126 . Yet other modes of manipulation of the sleeve such as  110  will be described below. 
       FIG. 11  shows a valve member  148  in a housing  150  that has port arrays  152  and  154  for example. Valve member  148  has unobstructed arrays  156  and  158  shown aligned with ports  152  and  154  to define the fracturing position. In this design the valve member  148  is secured to the housing  150  with a j-slot mechanism, two examples of which are illustrated in  FIGS. 14 and 15 . One way of manipulating the valve member  148  is to use a shifting tool (not shown) and grab an internal recess  160  so that a pickup or set down force can be applied to sleeve  148  to move it to the  FIGS. 12 and 13  positions by taking advantage of the j-slot assembly that movably secures the valve member  148  to the housing  150 .  FIG. 12  shows the valve member shifted from the  FIG. 11  position so that ports  152  and  154  are obstructed by valve member  148  to define the fully closed position.  FIG. 13  shows port arrays  160  and  162  that carry a filtering material, preferably sintered metal, and now in alignment with ports  152  and  154  which is the ready for production position that is used after fracturing is complete. Fracturing occurs with the components in the  FIG. 11  position. There are thus, three positions for the illustrated valve assembly which need definition in the j-slot mechanism. The j-slot in  FIG. 14  operates to change positions of the valve member  148  by a combination of a pick up and a set down of weight. When the pin (not shown) lands at the uppermost point  164  of the rolled open j-slot pattern shown in  FIG. 14  the valve member  148  is in the  FIG. 13  position for production with screening. In the  166  position, the valve member is in the fracturing position of  FIG. 11 . Finally, when the j-slot pin lands at position  168  the valve member  148  is in the closed position of  FIG. 12 . Alternatively, the three positions can be obtained with a j-slot that uses pick up and hold at point  170  of  FIG. 15  as the production with filtration position shown in  FIG. 13 . Position  174  for the j-slot pin corresponds to the fracture position of  FIG. 11  and position  172  corresponds to the closed position of  FIG. 12 . 
     Although a single sleeve is shown with two spaced arrays where at each location there are unobstructed and filtered ports there could be additional or fewer such arrays on a single valve member  148 . The closed position is optional. Movement of the valve member  148  can also be accomplished using pressure techniques as will be described below. 
     One such pressure technique is illustrated in  FIGS. 16-19 . Referring first to  FIG. 17  to see the overall assembly, a housing  176  joined by threaded connections has an annular wall recess  178  in which is mounted a movable piston  180  that has seals  182  and  184  and a port  186  that leads into recess  178 . Seals  188  and  190  allow the piston to reciprocate while holding pressure in recess  178 . Piston  180  divides recess  178  into variable volume cavities  192  and  194 . In  FIG. 17 , port  196  communicates with cavity  194 . Piston  180  is connected to valve member  198  that has an array of unobstructed openings  200  and an array of filtered openings  202 . A travel stop  204  defines the  FIG. 17  position where the array of ports  206  is closed by the valve member  198 . Housing  176  also has a series of spaced projections  208 ,  210  and  212  that are preferably on a predetermined spacing. Valve member  198  has a depression  214  shown in  FIG. 17  to be registered with projection  208  to hold the position of  FIG. 17  with ports  206  closed. 
     Referring now to  FIG. 16  for additional details, a running string  218  has an external seal  220  that is shown positioned between openings  186  and  196 . Piston  180  has a port  222  that permits pressure delivered through string  218  to go through port  196  and then through port  222  to reach cavity  194  to push piston  180  to the left or uphole. Movement of piston  180  uphole takes with it valve member  198  as recess  214  jumps over projections  208  and moves uphole until recesses  214  registers with projection  210 . This position is shown in  FIG. 18  and illustrates the alignment of array of filtration ports  202  with housing ports  206 . The registration of projections with depressions is but one way to assure that a predetermined movement of valve member  198  has occurred, in this case responsive to an applied pressure of a predetermined value. A removal of pressure when a spike is sensed simply holds the last obtained position. To get to the position of  FIG. 19  where unobstructed ports  200  line up with ports  206  to define the ready to fracture position, the pressure in string  218  while in the  FIG. 16  position, is simply raised again until recess  214  jumps over projection  210  and lands on projection  212 . At the same time, the valve member also hits travel stop  224 . The ready to fracture position of  FIG. 19  is now defined. Referring again to  FIG. 16 , as the piston  180  moves uphole or to the left, displaced fluid from above it exits port  186  and goes into annular space  226  between tubular string  218  and housing  176 . The movement of piston  180  can be reversed by simply applying pressure into annular space  226  to push down piston  180  while displacing fluid from cavity  194  through ports  222  and then  196  followed by a return into the string  218 . 
     Rather than relying on a pressure differential between the inside of string  218  and the annulus  226  around it as in  FIGS. 16-19 , an alternative using applied pressure is illustrated in  FIGS. 20-22 . The parts in the housing  176 ′ are identical to the  FIGS. 16-19  embodiment. What is different is that work string  230  has an internal sleeve  232  with a series of radial ports  234  that emerge between seals  236  and  238 . Annular cavities  240  and  242  are formed respectively between seal pairs  238  and  244  for cavity  242  and seals  236  and  246  for cavity  240 . Passage  248  fluidly connects cavities  240  and  242 . Passage  250  exits from cavity  242  through the wall of string  230  and above external seal  254 . Passage  252  exits cavity  240  between external seals  256  and  258 . Ports  234  provide a radial exit from within string  230  through its wall and between external seals  254  and  256 . Assuming string  230  is closed or can be closed at its lower end  260  or the extension of the tubular housing  176 ′ is closed to pressure below lower end  260 , applying pressure in the  FIG. 20  position directs pressure from ports  234  into cavity  192 ′ to move the piston  180 ′ as the cavity  192 ′ gets bigger while cavity  194 ′ gets smaller by displacing fluid through ports  222 ′ followed by ports  196 ′ followed by annulus  262 , which is equalized with cavities  240  and  242 . In this manner, the piston  180 ′ can be advanced to its other positions as previously described. 
     Referring to  FIG. 21  for opposite movement of the piston  180 ′, the ports  234  are now in fluid communication with ports  196 ′ instead of  186 ′ as in  FIG. 20 . Ports  250  are now in communication with the annulus  262 . Pressure applied from string  230  through ports  234  communicates to ports  196 ′ and then through ports  222 ′ to push piston  180 ′ in a direction to make cavity  194 ′ larger in volume and cavity  192 ′ smaller in volume. The displaced fluid from cavity  192 ′ goes through ports  186 ′, then into cavity  240 , then into cavity  242  through passage  248 , then through ports  250  and into annulus  262 . The resulting movement of the valve member (not shown in  FIGS. 20-22 ) is the same as described with regard to  FIGS. 16-19 .  FIG. 22  shows another way to get the same result as the position of the string  230  in  FIG. 20 . In  FIG. 22 , the pressure is simply delivered out the lower end  260  and goes into ports  186 ′. From there, the pressure enlarges cavity  192 ′ and displaces fluid from cavity  194 ′ in series through ports  222 ′,  196 ′,  252 , passage  248 , ports  250  and into annular space  262 . 
     Those skilled in the art will appreciate that the present invention allows for dual purpose ports in a tubular string that can accommodate fracturing and then be switched to filtration so that in an open hole completion, for example, there is no need to run in a screen assembly and a crossover tool. The ports can be configured for fracturing in any order needed and can have external isolators in the open hole between them so as to allow different portions of the wellbore to be treated individually or together as needed and in any desired order. By the same token, different regions can be produced or shut off as needed. The valve assembly can be two positions for fracturing and production or three positions by adding a closed position. Trips to the well can be reduced further by using the same run in string to deliver the completion string, move the valves in it as needed and also serve as the production string after putting the required valves in production mode. Different techniques can be used to actuate the valves including mechanical force, pressure and a j-slot combined with physical manipulation to name a few. The elimination of a crossover tool and a screen section not only saves rig time but eliminates the operational risks that are associated with using crossover tools and gravel packing screens, such as erosion in the crossover tool and bridging in the gravel pack. 
     An alternative embodiment is illustrated in  FIGS. 31-33 . In  FIG. 31  the tubular  300  has a fracturing port array  302  and a filtration port array  304  with a filer media  306  associated with each port  304 . A sliding sleeve  308  with an array of ports  310  to selectively match arrays  302  or  304  or neither for the closed position shown in  FIG. 31 .  FIG. 32  shows the fracturing position and  FIG. 33  shows the filtration position for production. The present invention incorporates the option of using a common port on the tubular with the filter material on the sliding sleeve or having sets of ports on the tubular with the filter material on one set of tubular ports and the other set wide open for fracturing as illustrated in  FIGS. 31-33 . 
     The above description is illustrative of the preferred embodiment and many modifications may be made by those skilled in the art without departing from the invention whose scope is to be determined from the literal and equivalent scope of the claims below.