Abstract:
A loss mitigation bottom hole assembly for use in a wellbore to isolate a severe loss zone of a formation, including a drill bit for drilling a well bore, and a dual wall drill string connecting the drill bit to a fluid source, and having a first fluid passage for delivering fluid to a drill bit, and a separate second fluid passage for returning the fluid away from the drill bit. The assembly further includes a drilling liner circumscribing and attached to a bottom portion of the dual wall drill string, and surrounding the drill bit, the drilling liner having an end adjacent the drill bit to contain the fluid exiting the drill bit and prevent the fluid from entering the severe loss zone of the formation.

Description:
CROSS-REFERENCE TO RELATED APPLICATIONS 
       [0001]    This application claims priority to U.S. Provisional Patent Appln. No. 62/102,927, which was filed on Jan. 13, 2015, the full disclosure of which is hereby incorporated herein by reference in its entirety. 
     
    
     FIELD OF THE INVENTION 
       [0002]    The present technology relates to drilling oil and gas wells. In particular, the present technology relates to drilling systems for use in reducing circulation loss using a dual-walled drill string capable of simultaneously drilling and lining loss zones. 
       BACKGROUND OF THE INVENTION 
       [0003]    In oil and gas drilling operations, hydrocarbon producing wellbores extend subsurface and intersect subterranean formations where hydrocarbons are trapped. The wellbores generally are created by drill bits attached to the end of a drill string, where typically a drive system above the opening to the wellbore rotates the drill string and bit. Drill bits are usually equipped with cutting elements that scrape the bottom of the wellbore as the bit is rotated to excavate material from the formation, thereby deepening the wellbore. Drilling fluid, also referred to as drilling mud, is typically pumped down the drill string and directed from the drill bit into the wellbore, where it then flows back up the wellbore in an annulus between the drill string and walls of the wellbore. The drilling fluid cools the bit, maintains a desired pressure in the well, and when flowing up the wellbore carries with it cuttings produced during drilling operations. 
         [0004]    Safe and efficient hydrocarbon well drilling practices are essential in the oil and gas industry. Among the most costly and challenging problems encountered in the industry involves the occurrence of lost circulation zones or “loss zones” in a wellbore. This phenomenon generally results from the drilling fluid flowing from the wellbore into the subterranean formations where the hydrocarbons of may be trapped. The resulting reduction or loss of flow in a well affected by lost circulation, which can exceed 100 bbl/hr, is detrimental in terms of both the financial loss and the resulting safety concerns, which may include the potential loss of well control. The elimination or alleviation of lost circulation zones is a priority for the industry, as billions of dollars are lost per year due to lost circulation in drilling operations through losses of drilling fluids, formation damage (e.g., if losses occur insude reservoir section) and its negative impact on hydrocarbon production, and the costs of addressing the phenomenon through, e.g. lost circulation materials (LCMs). In further consideration of the relevant potential environmental and regulatory issues, the prevention and remediation of circulation loss in drilling operations is highly desirable. 
       SUMMARY OF THE INVENTION 
       [0005]    One embodiment of the present technology provides a loss mitigation bottom hole assembly for use in a wellbore in a severe loss zone of a formation. The assembly includes a drill bit for drilling a well bore, and a dual wall drill string connecting the drill bit to a fluid source, and having a first fluid passage for delivering fluid to a drill bit, and a separate second fluid passage for returning the fluid away from the drill bit. In addition, the assembly includes a drilling liner circumscribing and attached to a bottom portion of the dual wall drill string, and surrounding the drill bit, the drilling liner having an end (such as a commonly known drill-shoe with rock cutting elements) adjacent the drill bit to contain the fluid exiting the drill bit and prevent the fluid from entering the severe loss zone of the formation. 
         [0006]    In some embodiments, the assembly can further include a liner running/setting tool for setting the drilling liner relative to a casing when the drilling liner reaches a desired location in the well bore bridging the severe loss zone of the formation. The liner running/setting tool can include a collet retainer nut circumscribing the dual wall drill string and moveable between a first position and a second position axially relative to the dual wall drill string, and a collet retainer nut activation mechanism controllable by an operator to move the collet retainer nut between the first position and the second position. Furthermore, the liner running/setting tool can include a packer element circumscribing the drilling liner and in mechanical communication with the collet retainer nut, the packer element in an unenergized state when the collet retainer nut is in the first position, and in an energized state when the collet retainer nut is in the second position, so that when the collet retainer nut activation mechanism moves the collet retainer nut from the first position to the second position, the packer element is energized and seals the space between the drilling liner and the casing, and a toothed liner hanger slip circumscribing the drilling liner and in mechanical communication with the packer element, the toothed liner hanger slip disengaged from the casing when the packer element is not energized, and lockingly engaged with the casing when the packer element is energized, the toothed liner hanger slip preventing relative movement between the drilling liner and the casing when lockingly engaged with the casing. In addition, the packer element can have an angled surface positioned for forced insertion between the drilling liner and the toothed liner hanger slip when the packer element is energized, the angled surface pushing a portion of the toothed liner hanger slip into engagement with the casing when the packer element is energized. 
         [0007]    In some embodiments, the loss mitigation bottom hole assembly can include a fluid return area adjacent the drill bit between the dual wall drill string and the drilling liner, the fluid return area receiving fluid exiting from the drill bit, and a cross-over port assembly providing fluid communication between the fluid return area and the second fluid passage. The cross-over port assembly can include a valve having a first end and a second end, and movable between an open position and a closed position, and a passage between the fluid return area and the second fluid passage bisected by the valve, the first end of the valve in pressure communication with the first fluid passage and the second end of the valve in pressure communication with the fluid return area, so that when pressure in the first fluid passage exceeds pressure in the fluid return area, the valve moves toward the open position. 
         [0008]    An alternate embodiment of the present technology includes a liner running/setting tool for setting a drilling liner relative to a casing adjacent a severe loss zone of a well, including a collet retainer nut circumscribing a drill string in a well and moveable between a first position and a second position axially relative to the drill string, and a collet retainer nut activation mechanism controllable by an operator to move the collet retainer nut between the first position and the second position. The tool further includes a packer element circumscribing the drilling liner and in mechanical communication with the collet retainer nut, the packer element in an unenergized state when the collet retainer nut is in the first position, and in an energized state when the collet retainer nut is in the second position, so that when the collet retainer nut activation mechanism moves the collet retainer nut from the first position to the second position, the packer element is energized and seals the space between the drilling liner and the casing. In addition, the tool further includes a toothed liner hanger slip circumscribing the drilling liner and in mechanical communication with the packer element, the toothed liner hanger slip disengaged from the casing when the packer element is not energized, and lockingly engaged with the casing when the packer element is energized, the toothed liner hanger slip preventing relative movement between the drilling liner and the casing when lockingly engaged with the casing. 
         [0009]    In some embodiments, the packer element can have an angled surface positioned for forced insertion between the drilling liner and the toothed liner hanger slip when the packer element is energized, the angled surface pushing a portion of the toothed liner hanger slip into engagement with the casing when the packer element is energized. In addition, the collet retainer nut activation mechanism can be a pump that applies hydraulic pressure to a surface of the collet retainer nut to push the collet retainer nut from the first position toward the second position. 
         [0010]    In alternate embodiments, the liner running/setting tool can further include a collet fixedly attached to the drill string, the collet fixedly engaged with the drilling liner when the collet retainer nut is in the first position, and releasably engaged with the drilling liner when the collet retainer nut is in the second position. In addition, the tool can include a pressure equalization passage fluidly connecting an area above the liner running/setting tool with an area below the running/setting tool to equalize pressure above and below the running/setting tool, as well as a check valve in the pressure equalization passage to open and close the pressure equalization passage to fluid communication. 
         [0011]    Another embodiment of the present technology provides a loss mitigation bottom hole assembly for use in a wellbore in a severe loss zone of a formation, including a drill bit for drilling a well bore, a dual wall drill string connecting the drill bit to a fluid source, and having a first fluid passage for delivering fluid to a drill bit, and a separate second fluid passage for returning the fluid away from the drill bit, a drilling liner circumscribing and attached to a bottom portion of the dual wall drill string, and surrounding the drill bit, the drilling liner having an end adjacent the drill bit to contain the fluid exiting the drill bit and prevent the fluid from entering the severe loss zone of the formation, a fluid return area adjacent the drill bit between the dual wall drill string and the drilling liner, the fluid return area receiving fluid exiting from the drill bit, and a cross-over port assembly providing fluid communication between the fluid return area and the second fluid passage. The cross-over port assembly includes a valve having a first end and a second end, and movable between an open position and a closed position, and a passage between the fluid return area and the second fluid passage bisected by the valve, the first end of the valve in pressure communication with the first fluid passage and the second end of the valve in pressure communication with the fluid return area, so that when pressure in the first fluid passage exceeds pressure in the fluid return area, the valve moves toward the open position. 
         [0012]    In some embodiments, the cross-over port assembly can further include a biasing mechanism in contact with the valve to bias the valve toward either the open or the closed position. In addition, the passage of the cross-over port assembly between the fluid return area and the second fluid passage can bisect the first fluid passage. 
         [0013]    Yet another embodiment of the present technology provides a method to control lost circulation in a severe loss zone in a subsurface formation. The method includes the steps of (a) drilling a well bore in the subsurface formation using a first bottom hole assembly until the well bore reaches a severe loss zone in the formation, (b) removing the first bottom hole assembly from the well bore, (c) running a second bottom hole assembly into the well bore, the second bottom hole assembly including a dual wall drill string, a drill bit, and a drilling liner extending to the end of the drill bit, (d) drilling through the severe loss zone using the second bottom hole assembly so that the drilling liner progresses through the severe loss zone along with the drill bit and prevents drilling fluid from entering the formation in the severe loss zone, and (e) removing the second bottom hole assembly from the well bore. 
         [0014]    In some embodiments, second bottom hole assembly includes a dual wall drill string assembly. In addition, the method can further include the steps of (f) setting the drilling liner relative to a casing in the well bore above the severe loss zone prior to step (e), and initiating step (f) by introducing a radio frequency identification (RFID) tag into the well to communicate with an RFID detector in the second bottom hole assembly. Furthermore, the method can include the step of running the first bottom hole assembly into the well to continue boring the well below the severe loss zone. 
     
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
         [0015]    So that the manner in which the features and advantages of the present technology, as well as others which will become apparent are attained and can be understood in more detail, a more particular description of the present technology briefly summarized above may be had by reference to the embodiments thereof which are illustrated in the appended drawings, which drawings form a part of this specification. It is to be noted, however, that the drawings illustrate only embodiments of the present technology and, therefore, are not to be considered limiting of its scope as the present technology may admit to other equally effective embodiments. 
           [0016]      FIG. 1  is a side cross-sectional view of a drilling system, according to an embodiment of the present technology, as the drill bit approaches a lost circulation zone; 
           [0017]      FIG. 2  is a side cross-sectional view of a well bore after drilling equipment is pulled from the well and before an apparatus of the present technology is inserted; 
           [0018]      FIG. 3  is a side cross-sectional view of a drilling system according to an embodiment of the present technology, with the drill bit and lining bridging the lost circulation zone; 
           [0019]      FIG. 4A  is a side cross-sectional view of a flow cross-over port for use in the drilling system of  FIG. 3 , according to an embodiment of the present technology, where the flow control valve is in the open position; 
           [0020]      FIG. 4B  is a side cross-sectional view of the flow cross-over port of  FIG. 4A , where the flow control valve is in the closed position; 
           [0021]      FIG. 5A  is a partial side cross-sectional view of a rotating liner setting tool for use in the drilling system of  FIG. 3 , according to an embodiment of the present technology; 
           [0022]      FIG. 5B  is a partial side cross-sectional view of the rotating liner setting tool of  FIG. 5A , with a gripping mechanism of the drilling liner engaged with a well casing; 
           [0023]      FIG. 5C  is a side cross-sectional view of a well casing and drilling liner according to an embodiment of the present technology, with the drilling liner set relative to the casing and the rotating liner setting tool removed from the well bore; and 
           [0024]      FIG. 6  is a side cross-sectional view of the wellbore after the lining of the present technology has been inserted across the lost circulation zone. 
       
    
    
     DETAILED DESCRIPTION OF THE INVENTION 
       [0025]    Embodiments of the present technology will now be described more fully hereinafter with reference to the accompanying drawings, which illustrate embodiments of the present technology. This technology may, however, be embodied in many different forms and should not be construed as limited to the illustrated embodiments set forth herein; rather, these embodiments are provided so that this disclosure will be thorough and complete, and will fully convey the scope of the present technology to those skilled in the art. Like numbers refer to like elements throughout. 
         [0026]    In preferred embodiments, the present technology can advantageously control lost circulation in a lost circulation zone in a wellbore. For instance, one embodiment of the present technology (described in greater detail below) enables the circulation of drilling mud and/or drilling fluid with drill cuttings returned to the top of the drill string through the inner string. This embodiment advantageously avoids the active circulation of any drilling mud, drilling fluid, and drill cuttings in the outer string or annulus, with the exception of a drilling fluid optionally circulated in an area where a drilling liner is operably set for controlling adjacent loss circulation zones. As will be understood by those skilled in the art, certain embodiments of the present technology, for example, also can reduce financial loss, safety concerns, regulatory issues and environmental impact. 
         [0027]    Referring now to the drawings, there is shown in  FIG. 1  a step of a method, according to an embodiment of the present technology. According to the step shown in  FIG. 1 , a bottom hole assembly (BHA)  10  that includes a drill string  12 , a mud motor  14 , and a drill bit  16 , can drill the well bore  18  according to known techniques, until the drill bit  16  reaches near the top of a severe loss zone  20  in the formation. During this initial step, drilling fluid can flow down through the drill string  12 , through the mud motor  14 , out the drill bit  16 , and back up the annulus  22  of the well bore  18 , according to the path  24 . In addition, during this initial step, a well casing  26  can be installed in the well bore  18  above the severe loss zone  20 . Next, as shown in  FIG. 2 , the BHA  10  can be withdrawn from the well bore  18  in preparation for the introduction of a loss mitigation BHA  28  (shown in  FIG. 3 ). 
         [0028]    Referring to  FIG. 3 , there is shown a loss mitigation BHA  28 , according to an embodiment of the present technology. The loss mitigation BHA  28  is designed to bridge the severe loss zone  20  and prevent or reduce the loss of drilling fluid into the formation as the drill bit passes through the sever loss zone  20 . The loss mitigation BHA  28  can include a rotating liner running/setting tool  30 , a dual wall drill string  32 , a flow cross-over port assembly  34 , a slip joint  36  or hydraulic thruster, a mud motor  38 , stabilizers  40 , a drill bit  42 , and a tight-clearance drilling liner  44 . The loss mitigation BHA  28  provides a structure capable of both drilling through the sever loss zone  20  using the drill bit  42 , and inserting a lining  44  into the well bore to prevent egress of drilling fluid from the loss mitigation BHA  28  into the formation, simultaneously. Each principle component of the loss mitigation BHA  28  will now be described in detail. 
         [0029]    The dual wall drill string  32  contains both an outer fluid passage  46 , and an inner fluid passage  48 . In the embodiment shown, drilling fluid travels along path  50  down the outer fluid passage  46  to the drill bit  42  where it is expelled to help cool the drill bit  42  and to carry cuttings and other debris away from the drill bit  42 . From the drill bit  42 , the drilling fluid travels back upward inside the drilling liner  44  to the flow cross-over port assembly  34  (described in greater detail below with regard to  FIGS. 4A and 4B ). The drilling fluid enters the inner fluid passage  48  of the dual wall drill string  32  via the flow cross-over port assembly  34 , and travels away from the drill bit  42  toward the top of the well. Use of the dual wall drill string  32  in the loss mitigation BHA  28  allows for the components of the loss mitigation BHA  28  to form a substantially closed system  28 , thereby reducing the ability of drilling fluid to enter the formation in the severe loss zone  20 . 
         [0030]    The slip joint  36  connects that bottom of the dual wall drill string  32  to the mud motor  38 , and the mud motor  38  pumps the drilling fluid to the drill bit  42 . The mud motor  38  thus serves to help circulate the drilling fluid through the loss mitigation BHA  28 . The drill bit  42  is attached to the mud motor  38 , and rotates to cut into the formation and extend the well bore  18 . The drill bit  42  heats as it rotates, in large part because of the friction between the drill bit  42  and elements that make up the formation. The flow of drilling fluid helps to cool the drill bit  42  as it rotates. In addition, as the drill bit cuts into the formation, it generates cuttings and other debris. The drilling fluid helps to carry away such cuttings and debris generated by the drill bit  42 . 
         [0031]    The drilling liner  44  surrounds the other components of the loss mitigation BHA  28 , and progresses through the well bore  18  along with the drill bit  42  as the drill bit  42  cuts the well bore  18 . At its upper end, the drilling liner  44  surrounds the dual wall drill string  32 , with components of the liner running/setting tool  30  covering the gap and providing a seal between the drilling liner  44  and the dual wall drill string  32 . This seal contains the drilling fluid within the loss mitigation BHA  28  as it flows from the drill bit  42  to the flow cross-over port assembly  34 , and blocks the fluid from communicating with the annulus  22  of the well bore  18 . Such containment is beneficial to provide the hydraulic forces that control of the cross-over port assembly  34 , as discussed in detail below. In addition to the above, the drilling liner  44  is rotated as it progresses during the drilling operation. Such rotation causes a plastering or smearing effect on the walls of the bore through the severe loss zone, which helps to further seal the walls of the well bore to that drilling fluid is not lost into the formation. 
         [0032]    For simplicity, the running/setting tool  30  is shown only schematically in  FIG. 3 . The running/setting tool  30  is shown in greater detail in  FIGS. 5A-5C . By enclosing the loss mitigation BHA  28 , including the drilling fluid, and progressing down the well bore along with the drill bit  42 , the drilling liner  44  substantially prevents the drilling fluid from entering the formation at the sever loss zone  20 . Once the loss mitigation BHA  28  has been inserted into the well bore  18  so that the drilling liner  44  bridges the severe loss zone  20 , the drilling liner  44  can be set relative to the hanger using the running/setting tool  30  (as described in greater detail below with regard to  FIGS. 5A-5C ). 
         [0033]      FIG. 4A  shows an enlarged cross-sectional view of the flow cross-over port assembly  34 , including the valve  52  and valve openings  54 . As shown, valve openings  54  provide a fluid path  56  between an area  58  outside of the dual wall drill string  32 , and the inner fluid passage  48  of the dual wall drill string  32 . The valve  52  can be positioned in a recess  60  in a wall of the dual wall drill string  32 , and can be configured to translate axially in the recess  60  between an open position (shown in  FIG. 4A ) and a closed position (shown in  FIG. 4B ). In some embodiments, the valve  52  can have a spring  62  or other biasing mechanism to help push the valve  52  toward the open or the closed position. 
         [0034]    Also shown in  FIGS. 4A and 4B  are hydraulic ports  66 ,  68 . Hydraulic port  66  provides pressure communication between an upper end of the valve  52  and the drilling fluid in the outer fluid passage  46  of the dual wall drill string  32 . Small hydraulic hole or port  68  provides pressure communication or ventilation between a lower end of the valve  52  and the area  58  outside the dual wall drill string  32 . Thus, the valve  52  is balanced by the pressure in the outer fluid passage  46  and the pressure in the area  58  outside the dual wall drill string  32 . 
         [0035]    As shown in  FIG. 4A , when the pressure in the outer fluid passage  46  of the dual wall drill string  32  exceeds the pressure in the area  58  outside the dual wall drill string  32 , a pressure differential develops across the valve  52 , overcomes the force of spring  62 , and the valve  52  moves downward in the recess  60  toward an open position. When in such open position, the valve opening  54  substantially aligns with a passage  70  between the inner fluid passage  48  and the area  58  outside the dual wall drill string  32 , so that fluid can flow into the inner fluid passage  48  from area  58 . Since pressure in the outer fluid passage  46  will be highest when drilling fluid is being pumped down the well, this means that the valve  52  will be open when fluid is circulating through the loss mitigation BHA  28 . 
         [0036]    Conversely, as shown in  FIG. 4B , when fluid circulation through the loss mitigation BHA  28  is stopped and pump pressure is bled off at the surface, the pressure in the area  58  outside the dual wall drill string  32  substantially equalizes with the pressure in the outer fluid passage  46 , and a little pressure differential develops across the valve  52 , so that the compressed force from bias spring  62  will be released that moves the valve  52  upward in the recess  60  toward a closed position. When in such closed position, the valve opening  54  is not aligned with the passage  70  between the inner fluid passage  48  and the area  58  outside the dual wall drill string  32 , so that fluid is prevented from flowing into the inner fluid passage  48  from area  58 . 
         [0037]      FIGS. 5A and 5B  show details of the running/setting tool  30  at different stages it sets the drilling liner  44  relative to the casing  26 . Specific components that can be included in the example embodiment shown include a radio frequency identification (RFID) tag  72 , an RFID detector  74 , a hydraulic chamber  76  that may contain a piston  78  and isolated piston fluid, a collet  80 , a collet retainer nut  82 , a packer element  84 , and a liner hanger slip  86 . The liner hanger slip  86  can have teeth  88  for engaging the casing  26 . Also shown in  FIGS. 5A and 5B  is a clutch mechanism  89 , and a pressure equalization passage  91  with a check valve  93 . The clutch mechanism can be used to engage the dual wall drill string  32  with the top of the drilling liner  44  to enable transmission of rotating torque from the surface to rotate the drilling liner  44  for the purpose of achieving liner drilling. The pressure equalization passage  91  can help to equalize pressure between the well annulus  18  and the area  58  inside the drilling liner  44 , and can be opened or closed using the check valve  93 . 
         [0038]    Referring specifically to  FIG. 5A , the running/setting tool  30  is shown in a disengaged state, as it would be while the running/setting tool  30  is traveling down the well to its intended location near the severe loss zone  20 . While is such a disengaged state, the liner hanger slip  86  is substantially aligned with the drilling liner  44  so that the teeth  88  are separated from the casing  26 . The packer element  84  is located above the liner hanger slip  86 , and has an angled surface  90  positioned so that when the packer element is pushed downward relative to the drilling liner  44 , the angled surface  90  wedges in the interface between the liner hanger slip  86  and the drilling liner  44 , and pushes one end of the liner hanger slip  86  forward until the teeth  88  engage the casing  26  (as shown, for example, in  FIG. 5B ). Also while in the disengaged state, the collet  80  engages the drilling liner  44  by means of a protrusion  92  that extends into a corresponding recess  94  in the hanger. The collet  80  is held in place, with the protrusion  92  engaging the recess  94 , by the collet retainer nut  82 . 
         [0039]    The collet retainer nut  82  is movable between a first position (shown in  FIG. 5A ) and a second position (shown in  FIG. 5B ). In addition, the collet retainer nut  82  has two ends that perform separate but simultaneous functions. The first end  96  of the collet retainer nut  82  is located near the protrusion  92  of the collet  80 , and includes a recess  98 . When the collet retainer nut  82  is in the first position, shown in  FIG. 5A , the recess  98  is not aligned with the protrusion  92 . Instead, the body of the collet retainer nut  82  abuts the collet  80  so that the protrusion  92  is held firmly in place in the recess  94  of the drilling liner  44 . Conversely, when the collet retainer nut  82  is in the second position, shown in  FIG. 5B , the recess  98  aligns with the collet  80  such that the end of the collet  80  can flex inward, thereby allowing the protrusion  92  to disengage from the recess  94  of the drilling liner  44 . 
         [0040]    The second end  100  of the collet retainer nut  82  is located above the packer element  84 . When the collet retainer nut  82  is in the first position, shown in  FIG. 5A , the second end  100  of the collet retainer nut  82  abuts the packer element  84  while the packer element is positioned above the liner hanger slip  86 , as discussed above. Conversely, when the collet retainer nut  82  is in the second position, shown in  FIG. 5B , the second end  100  of the collet retainer nut  82  pushes the packer element  84  downward so that the angled surface  90  of the packer element  84  wedges behind the liner hanger slip  86 , also as discussed above. Such action pushes the teeth  88  of the liner hanger slip into engagement with the casing  26 . 
         [0041]    The position of the collet retainer nut  82  between the first position and the second position can be controlled by hydraulic pressure in the hydraulic chamber  76 . Pressure communication is provided between the hydraulic chamber  76  and a shoulder  102  on the collet retainer nut  82  via a port  104 . As hydraulic pressure in the hydraulic chamber  76  and port  104  increases, such pressure applies a downward force on the shoulder  102 , thereby pushing the collet retainer nut  82  from the first position toward the second position. Hydraulic pressure in the hydraulic chamber  76  and port  104  can be controlled by any appropriate means, such as, for example, an electric pump  106  which may use a piston  78  or other means to increase or decrease pressure in the hydraulic chamber  76  and port  104 . 
         [0042]    To determine when to set the drilling liner  44  relative to the casing  26 , one embodiment of the present technology includes use of the RFID tag  72  and detector  74 . The RFID detector can be attached to, or embedded as part of, the running/setting tool  30 . When an operator desires to set the drilling liner  44 , the operator can send the RFID tag  72  down the outer fluid passage  46  of the dual wall drill string  32 . When the RFID tag reaches a predetermined proximity to the RFID detector  74 , the RFID detector  74  can instruct the electric pump  106  to increase hydraulic pressure in the hydraulic chamber  76  and port  104  to move the collet nut retainer  82  from the first position toward the second position. 
         [0043]    The process of setting the drilling liner  44  relative to the casing  26  includes running the running/setting tool  30  into the well with the loss mitigation BHA  28  until the loss mitigation BHA  28  reaches a desired location in the well. This location typically corresponds to the bridging of a severe loss zone by the drilling liner  44 . Then, the RFID tag  72  can be deployed to instruct the RFID detector, which in turn triggers the electric pump  106  to set the drilling liner  44 . 
         [0044]    To set the drilling liner  44 , the electric pump  106  can increase the hydraulic pressure in the hydraulic chamber  76  and the port  104  via the movement of piston  78 . This will move the collet nut retainer  82  from the first position toward the second position. As the collet nut retainer  82  moves from the first position toward the second position, the recess  98  in the collet net retainer  82  aligns with the end of the collet  80 , adjacent the protrusion  92 . At the same time the second end  100  of the collet nut retainer  82  pushes the packer element  84  downward. As the packer element  84  moves downward, the angled surface  90  inserts between the liner hanger slip  86  and tilts the liner hanger slip  86  toward the casing  26  until the teeth  88  of the liner hanger slip  86  engage the casing  26 . With the teeth so engaged, the drilling liner  44  is set relative to the casing  26 . As the packer element  84  moves downward, it also expands to seal the gap between the drilling liner  44  and the casing  26 , as shown in  FIG. 5B . 
         [0045]    Once the hanger  44  is set relative to the casing  26 , and the packer element is energized to seal the gap between the hanger  44  and the casing  26 , the running/setting tool  30  can be withdrawn from the well. To accomplish this, the dual wall drill string  32  is pulled out of the well bore. As the dual wall drill string  32  is lifted, the end of the collet  80  deflects inwardly into the recess  98  of the collet nut retainer  82  and the protrusion  92  disengages from the recess  94  in the drilling liner  44 . As shown in  FIG. 5C , all of the components but the drilling liner  44 , liner hanger slip  86 , and packer element  84  can be removed from the well. 
         [0046]      FIG. 6  shows the completed well bore after the running/setting tool  30  and loss mitigation BHA  28  components have been removed from the well. As shown, the drilling liner  44  is in place bridging the severe loss zone  20  and is set and sealed relative to the casing  26  at the upper end of the drilling liner  44 . The bottom end of the drilling liner  44  is positioned below the severe loss zone  20  and remains open so that regular drilling operations can continue to extend the depth of the well bore if desired. 
         [0047]    Certain embodiments contemplate use of the present technology for the deployment of a tight-clearance drilling liner in a well for isolating a severe less zone in a most time efficient manner without losing much resulting hole size available for the continued drilling of the next hole section. A skilled artisan will appreciate that such drilling and subsurface wellbore formation will advantageously require less cement, mud, drilling fluid and downhole casing and tubing, thereby reducing operational, drilling and material costs. 
         [0048]    In some embodiments of the present technology, the drilling liner  44  can any commercially available drilling liner, for instance 1) a 16 inch drilling liner for use below an 18⅝ inch casing show, b) an 11¾ inch drilling liner for use below a 13⅜ inch casing shoe, and c) an 8 inch drilling liner for use below a 9⅝ inch casing shoe, while the dual wall drill string  32  can be standard 6⅝ inch and or 5½ inch drillpipe with a smaller connectable inner tube. 
         [0049]    Many modifications and other embodiments of the technology will come to the mind of one skilled in the art having the benefit of the teachings presented in the foregoing descriptions and the associated drawings. Therefore, it is to be understood that the technology is not to be limited to the illustrated embodiments disclosed, and that modifications and other embodiments are intended to be included within the scope of the appended claims. 
         [0050]    Unless defined otherwise, all technical and scientific terms used have the same meaning as commonly understood by one of ordinary skill in the art to which this technology belongs. 
         [0051]    The singular forms “a,” “an,” and “the” include plural referents, unless the context clearly dictates otherwise. 
         [0052]    As used herein and in the appended claims, the words “comprise,” “has,” and “include” and all grammatical variations thereof are each intended to have an open, non-limiting meaning that does not exclude additional elements or steps. 
         [0053]    “Optionally” means that the subsequently described event or circumstances may or may not occur. The description includes instances where the event or circumstance occurs and instances where it does not occur. 
         [0054]    Ranges may be expressed herein as from about one particular value, and/or to about another particular value. When such a range is expressed, it is to be understood that another embodiment is from the one particular value and/or to the other particular value, along with all combinations within the range. 
         [0055]    Although the present technology has been described in detail, it should be understood that various changes, substitutions, and alterations can be made hereupon without departing from the principle and scope of the technology. Accordingly, the scope of the present technology should be determined by the following claims and their appropriate legal equivalents.