Patent Publication Number: US-10760347-B2

Title: System and method for offline suspension or cementing of tubulars

Description:
BACKGROUND 
     A cement job is performed when the drilling has lowered the casing in the well-bore. A cement job is the process of mixing a slurry of cement, cement additives and water and pumping it down through casing to critical points in the annulus around the casing or in the open hole below the casing string. Cement supports and protects well casings and helps achieve zonal isolation. Critical to safer, environmentally sound, and profitable wells, zonal isolation is created and maintained in the wellbore by the cementing process. The cement is deigned based on various well parameters, e.g., depth, wellbore geometry, temperature, pressure, and formation composition. 
     A casing profile includes multiple casing strings, such as conductor casing, surface casing, intermediate casing and production casing. Furthermore, each casing string undergoes a cement job. The large-diameter conductor casing protects shallow formations from contamination by drilling fluid and helps prevent washouts involving unconsolidated topsoils and sediments. Surface casing, the second string, has a smaller diameter, maintains borehole integrity and prevents contamination of shallow groundwater by hydrocarbons, subterranean brines and drilling fluids. The intermediate casing isolates hydrocarbon-bearing, abnormally pressured, fractured and lost circulation zones, providing well control as engineers drill deeper. Multiple strings of intermediate casing may be required to reach the target producing zone. The production casing, or liner, is the last and smallest tubular element in the well. It isolates the zones above and within the production zone and withstands all of the anticipated loads throughout the well&#39;s life. 
     Once the wellbore is lined with a casing, a cement head is installed above the rig floor to introduce cement into the well. The cement is pumped thru various cement lines traveling thru the cement head and into the well. During the cementing operation, the casing is typically supported by the rig hook and travelling block or the rotary table of the drilling rig. Furthermore, performing the cement job in oil and gas wells typically requires the drill-rig to be standing above the well during the operation for a fair amount of time (which can be up to a few days of non-productive time). 
     When multiple wells are drilled on a pad (land application), the drilling sequence may be based on batch drilling. With such process, the corresponding sections of all wells are drilled in series, requiring the rig to be moved from well to well after each section. Typically, a well section is drilled; then the casing is lowered into the well-bore and then cemented. The rig is not moved until after the cement has set, causing significant non-productive time. 
     SUMMARY OF DISCLOSURE 
     In one or more embodiments, a system for offline suspension of a tubular may include a first well, having a first wellbore and a cellar formed at the surface of the first well; a rig movable from the first well to a second well; a tubular string extending into the first well; and a tubular support structure above the cellar of the first well, wherein the tubular support structure supports a weight of the tubular string such that the tubular is suspended from the tubular support structure independent from the rig and through a securing equipment configured to secure the first well. 
     In one or more embodiments, a system for offline suspension of a tubular may include a rig movable from a first well to a second well; a first tubular string cemented in place within in the first well; a wellhead attached to the first tubular string and having a landing spool therein; a second tubular string extending into the first well through the wellhead and the first tubular string; a hanger attached to the upper end of the second tubular string, the hanger configured to engage the landing spool such that the tubular string hangs in tension from the wellhead upon engagement of the hanger with the landing spool; and a landing tool disposed above the wellhead and engaged with the tubular string. 
     In one or more embodiments, a method for using a rig may include supporting a weight of a first tubular string with the rig at a first well; transferring the weight of the first tubular string from off of the rig prior to cementing the first tubular string in place; and moving the rig from the first well. 
     This summary is provided to introduce a selection of concepts that are further described below in the detailed description. This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter. 
    
    
     
       BRIEF DESCRIPTION OF DRAWINGS 
         FIG. 1  illustrates a view of a system for offline running or cementing of tubulars suspended in a well according to one or more embodiments of the present disclosure. 
         FIG. 2  illustrates a view of a system for offline running or cementing of tubulars suspended in a well under pressure according to one or more embodiments of the present disclosure. 
         FIG. 3  illustrates a view of a system for preparing offline cementing of tubular with a tubular support bridge according to one or more embodiments of the present disclosure. 
         FIG. 4  illustrates a view of a system for offline cementing of tubular according to one or more embodiments of the present disclosure. 
         FIG. 5  illustrates a view of a system for preparing offline cementing of tubular with a blowout preventer (BOP) Winch according to one or more embodiments of the present disclosure. 
         FIG. 6  illustrates a view of a system for preparing offline cementing of tubular with a rolling bridge according to one or more embodiments of the present disclosure. 
         FIG. 7  illustrates a top view of a rolling bridge according to one or more embodiments of the present disclosure. 
         FIG. 8  illustrates a view of a system for preparing offline cementing of tubular with a rolling bridge and a blowout preventer (BOP) winch according to one or more embodiments of the present disclosure. 
         FIG. 9  illustrates a view of a system for offline cementing of tubular in presence of a well-head according to one or more embodiments of the present disclosure. 
         FIG. 10  illustrates a view of a system for offline cementing with tubular reciprocation according to one or more embodiments of the present disclosure. 
     
    
    
     DETAILED DESCRIPTION 
     Embodiments of the present disclosure are described below in detail with reference to the accompanying figures. Like elements in the various figures may be denoted by like reference numerals for consistency. Further, in the following detailed description, numerous specific details are set forth in order to provide a more thorough understanding of the claimed subject matter. However, it will be apparent to one having ordinary skill in the art that the embodiments described may be practiced without these specific details. In other instances, well-known features have not been described in detail to avoid unnecessarily complicating the description. 
     Further, embodiments disclosed herein are described with terms designating orientation in reference to a vertical wellbore, but any terms designating orientation should not be deemed to limit the scope of the disclosure. For example, embodiments of the disclosure may be made with reference to a horizontal wellbore. It is to be further understood that the various embodiments described herein may be used in various orientations, such as inclined, inverted, horizontal, vertical, etc., and in other environments, such as sub-sea, without departing from the scope of the present disclosure. The embodiments are described merely as examples of useful applications, which are not limited to any specific details of the embodiments herein. 
     Embodiments of the present disclosure may be directed to systems and methods for the off-line running, suspending, or cementing of tubulars within a well. That is, tubular string may be run, suspended, and/or cemented in place within a well when a rig is no longer centered above the well, such as with a walkable rig. Thus, as or after the walkable rig has moved from a first well to a second well, the tubular in the first well may be run, suspended, and/or cemented in place without being supported by the rig in the conventional ways (travelling block or rotary table). When multiple wells are drilled on a pad (i.e. a land operation), the drilling sequence may be based on batch drilling. With such process, the corresponding sections of all wells are drilled in series, requiring the rig to be moved from well to well after each section. Typically, a well section is drilled; then the tubular is lowered into the well-bore. In conventional operations, the rig would suspend tubulars therein and would not be moved to a second well until after the first well&#39;s tubular has been cemented in place. In contrast, embodiments of the present disclosure provide for the tubular in the first well to be run, suspended, and/or cemented in place without being supported by the rig conventional methods, thus presenting a significant time and cost-savings where drilling of the second well can commence during the pumping of cement and/or curing of the cement in the first well, for example. As we discussed herein, running tubulars into the well, suspending, rotating, reciprocating, pumping through tubulars, pumping through annulus of tubulars, or even pulling tubulars out of the well (in the event of an emergency), with the weight of the tubular being held or supported by a structure other than the rig (so that the rig is free to be moved off of the well) are all envisioned as being embodiments of the present disclosure. 
     Various embodiments that allow for support of the tubular are envisioned and such embodiments may depend on the stage of the well in which the tubular is being emplaced. For example, the tubular can be supported by a system which may be independent of the rig&#39;s horizontal movement. Thus, the tubular may be attached to either a temporally installed structure below the rig floor, or to some rig components below the rig floor which may have some mechanical freedom in the horizontal plane (such as a rolling structure on horizontal rail). For some later sections, the tubular could also be landed in the well-head associated with previously cemented casing. Then the rig may be moved sideways (skidding or walking) towards the next the well to drill. In some instances, it may be desirable to cement the tubular in the well. Thus, as soon as the rig is moved or on the move, the cementing operation in the first well may be performed. After the cement job is completing, work at (or near) the well-head may be completed to secure the well. 
     Further, embodiments disclosed herein are described with terms designating in reference to a tubular, but any terms designating should not be deemed to limit the scope of the disclosure. For example, the tubular string is made up of numerous tubular pipes joined end-to-end, and each of the tubular pipes might be about twenty to forty feet in length. Further, the tubular pipes are hollow and thus provide a continuous channel of communication between the drill rig and the bottom of the wellbore, down through which a suitable fluid can be introduced to any region required within the well. It is to be further understood that the various embodiments described herein may be used with various types of tubulars, including but not limited to casing, without departing from the scope of the present disclosure. A casing generally refers to a large-diameter pipe that is lowered into an open hole and cemented in place. 
     As shown in  FIG. 1 , a system for offline suspension of a tubular in a well, in one or embodiments, is shown. In one or more embodiments, a first well  122 , not under pressure, has a cellar  111 . The cellar  111  may have a width of 6 feet by 8 feet in one or more embodiments; however, it is recognized that there is no limitation on the size of the cellar and it may take any shape or size for the purpose of the present disclosure. The cellar is commonly the first step toward the construction of the well. Additionally, the cellar may be made by a crew of workers before the drilling rig is brought to location. Furthermore, a conductor string  113  will extend a depth commonly of less than 100 feet into a wellbore  90  of the first well  122 . The conductor string  113  is generally the first tubular string that is placed in a well (often into an unconsolidated formation), and will have the largest outer diameter of all of the eventual tubular that is run downhole in the first well  122 . Conductor string  113  supports the surface formation from washout and may be placed during drilling or may be driven into place before drilling commences. Generally, the conductor string  113  is installed on location by the crew of workers before the drilling rig is brought to location. 
     Still referring to  FIG. 1 , in one or more embodiments, a tubular string  114  is being suspended in place. A weight of the tubular string  114  is suspended from a tubular support structure (which may take various forms, including the embodiments described in detail below) that is independent from any rig used to drill the well  122 . While suspended from tubular support structure, tubular string  114  may also extend through a security equipment  134  that may be provided to secure the well in the event of a well control incident. The type of security equipment  134  is no limitation, and may be, for example, a blind shear ram or a tubular ram. Optionally, a cement head  301  may be installed at the top end of tubular string  114  in order to pump a cement slurry through the tubular string  114  and into the annulus via a plurality of cement lines  302  attached to the cement head  301 . Specifically, the cement slurry may be pumped into the first well  122 , down the inner diameter of the tubular string  114  and into the annulus created between the tubular string  114  and wellbore  115  according to conventional practices in the art for any cement job (see dotted arrow line). It is also envisioned that fluids other than cement may be pumped into the tubular  114  or into the annulus surrounding tubular  114  while the tubular  114  is suspended in the well by the tubular support structure. 
     After the cement is pumped downhole and displaced into the annulus, waiting on cement occurs prior to assessing whether the top of cement meets regulatory and safety requirements. In the event that any remedial cement jobs may need to be performed, they can be done at this time, including a top job using a small-diameter (macaroni) pipe (not shown) in the annulus or the tubular string  114  that may be perforated to circulate cement into the annulus via these perforations (not shown). Following the completion of the cement job, the well may be secured by a flange (not shown) attached onto a wellhead (not shown). 
     As mentioned, the cement slurry may be displaced into the annulus, thereby displacing a wellbore fluid from the annulus out of the well  122 . Thus, a return line  131  may be installed either above or below the security equipment  134  in order to displace fluids (which may be cement slurry but also may be drilling or other wellbore fluids) from the annulus to a tank (not shown). Whether the return line  131  is above or below the security equipment  134  may depend, for example, on how the tubular is hung in the well and whether a flow path for the fluid exists above the security equipment  134 . For example, if a tubular hanger (not shown) is fluted, the return line  131  may be installed above the security equipment  134  instead of below (as shown by arrow  132 ). 
     As shown in  FIG. 2 , a system for offline suspension of tubular in a well under pressure, in one or embodiments, is shown. In one or more embodiments, a first well  122 , under pressure, has a cellar  111 . The cellar  111  may have a width of 6 feet by 8 feet in one or more embodiments; however, it is recognized that there is no limitation on the size of the cellar and it may take any shape or size for the purpose of the present disclosure. The cellar is commonly the first step toward the construction of the well. Additionally, the cellar may be made by a crew of workers before the drilling rig is brought to location. Furthermore, a conductor string  113  will extend a depth commonly of less than 100 feet into a wellbore  90  of the first well  122 . The conductor string  113  is generally the first tubular string that is placed in a well (often into an unconsolidated formation), and will have the largest outer diameter of all of the eventual tubular string that is run downhole in the first well  122 . Conductor string  113  supports the surface formation from washout and may be placed during drilling or may be driven into place before drilling commences. Generally, the conductor string  113  is installed on location by the crew of workers before the drilling rig is brought to location. 
     Still referring to  FIG. 2 , a weight of the tubular string  114  is suspended from a pushing equipment  133  (independent from any rig used to drill the well) and/or tubular support structure shown in the various embodiments below. The pushing equipment  133  is supported (directly or indirectly) by a floor  123  above the cellar  111 . Additionally, a security equipment  134 , such as a blind shear ram or a tubular ram, is below the pushing equipment  133  and engaged with the tubular string  114  to seal off the annulus created between the tubular string  114  and wellbore  115 . Optionally, the tubular string  114  may be cemented in place. Thus, above the pushing equipment  133 , a plurality of cement lines  302  are attached to a cement head  301 . A cement slurry (not shown) is pumped through the plurality of cement lines  302  and through the cement head  301  and down through the tubular string  114  into the first well  122 . The cement slurry may be pumped into the first well  122 , down the inner diameter of the tubular string  114  and into the annulus created between the tubular string  114  and wellbore  115  according to conventional practices in the art for any cement job (see dotted arrow line). Additionally, the pushing equipment  133  may push the tubular string  114  into the wellbore  115  due to the well being under pressure. The pushing equipment  133  may help place the tubular string  114  at a predetermined depth and displace the cement slurry evenly throughout the annulus. After the cement is pumped downhole and displaced into the annulus, waiting on cement occurs prior to assessing whether the top of cement meets regulatory and safety requirements. In the event that any remedial cement jobs may need to be performed, they can be done at this time, including a top job using a small-diameter (macaroni) pipe (not shown) in the annulus or the tubular string  114  that may be perforated to circulate cement into the annulus via these perforations (not shown). Following the completion of the cement job, the well may be secured by a flange (not shown) attached onto a wellhead (not shown). Since the security equipment  134  seals off the annulus, a return line  131  may be installed below the security equipment  134  in order to displace the wellbore fluid from the annulus to a tank (not shown) as the cement slurry is pumped into the annulus. 
     As shown in  FIG. 3 , a system for preparation of offline suspension of a tubular in a top section of a well, in one or embodiments, is shown. Referring to  FIG. 3 , a walking rig  121  is positioned over a first well  122  in preparation for offline suspension according to one or more embodiments of the present disclosure is shown. A second well  117  may be spaced apart, such as by 6 feet to 20 feet, from the first well  122 . However, there is no limitation on the spacing between the wells. In one or more embodiments, each of first well  122  and second well  117  have a cellar  111 ,  118 , respectively. The cellar  111 ,  118  may have a width of 6 feet by 8 feet in one or more embodiments; however, it is recognized that there is no limitation on the size of the cellar and it may take any shape or size for the purpose of the present disclosure. The cellar is commonly the first step toward the construction of the well. Additionally, the cellar may be made by a crew of workers before the drilling rig is brought to location. Furthermore, a conductor string  113 ,  119  will extend a depth commonly of less than 100 feet into a wellbore  90  of the first well  122  and a wellbore  91  of the second well  117 , respectively. The conductor string  113 ,  119  is generally the first tubular string that is placed in a well (often into an unconsolidated formation), and will have the largest outer diameter of all of the eventual tubular string that is run downhole in each well  122 ,  117 . Conductor string  113 ,  119  supports the surface formation from washout and may be placed during drilling or may be driven into place before drilling commences. Generally, the conductor string  113 ,  119  is installed on location by the crew of workers before the drilling rig is brought to location. 
     When drilling a first section  115  of the well  122  with the walking rig  121 , a drilling fluid is pumped into the well  122  and may return to surface through the bore of the conductor pipe  113  and may accumulate in the cellar  111 . A cellar pump  112  may be disposed in the cellar  111  to ensure the cellar  111  is kept clean of debris and liquids while operations are being performed on the first well  122 . A cellar pump line  120  shows the path at which debris and liquids travel out of the cellar  111  of the first well  122 . It is understood that each subsequent well, including second well  117 , may have a similar cellar, cellar pump, etc. 
     The walking rig  121 , according to one or more embodiments, may be movable from first well  122  to second well  117 , without necessitating disassembly and reassembly. The design or nature of the walkability or the skiddability is not a limitation on the present disclosure. In fact, the present disclosure may be used in conjunction with any walkable rig or even non-walkable rig that may be moved from first well  122  to second well  177 ; however, the convenience of a walking rig may be beneficial. However, as shown, walking rig  121  includes a substructure  105  having a rig floor  104  and a mast  100  disposed on the rig floor  104 . The mast  100  has a traveling block  102  powered by a drawwork  101 , which is disposed on the rig floor  104 . As seen in  FIG. 3 , the walking rig  121  is positioned on the first well  122 , such that the substructure  105  is disposed on a floor  123  above the cellar  111  of the first well  122 . In  FIG. 3 , the substructure(s)  105  are shown perpendicular to the direction of the two (or more) cellars for explanation purposes. However, one of ordinary skill in art would appreciate that in most applications, the substructure  105  is parallel to the direction defined by the cellars  111 ,  118 . With such overall design, the rig  104  can easily walked for the position shown in  FIG. 3  (above the well  122 ) to the location above the cellar  118  of the well  117 . Tubular string  114  may be placed in the well by conventional means such as an upper tubular elevator  103  in conjunction with a landing tool. Specifically, as shown, upper tubular elevator  103  is connected to the traveling block  102 , and the upper tubular elevator  103  engages an upper landing tool  106 . The upper landing tool  106  may engage a lower landing tool  107 , and both are used to aid in the lowering the tubular string  114  which may include a wellhead  110  into the wellbore  115  of the first well  122 . Furthermore, a plurality of tubular centralizers or scrapers (not shown here, but shown, for example, in  FIG. 9 ) may optionally be used to keep the tubular string centered in the wellbore  115 . The lower landing tool  107  further engages the tubular string  114  optionally within the wellhead  110 . In one or more embodiments, a plurality of floats valves  116  may be disposed in the wellbore  115  at the bottom of the tubular string  114 . While the tubular string  114  is emplaced and supported by upper tubular elevator  103  in conjunction with upper landing tool  106  and lower landing tool  107  optionally through wellhead  110 , in accordance with the present disclosure, the weight of tubular string  114  may be transferred off of such components (and the rig generally) in preparation for and during the offline suspension (and optional cementing) of the tubular string  114 . In one or more embodiments, the bottom of the tubular string  114  may be a minimum of 10 feet away from the bottom of the wellbore  115 . Further, the length of the tubular string  114  is determined by well parameters and is not a limitation on the scope of the present disclosure. 
     As mentioned above, in accordance with methods of the present disclosure, the weight of the tubular is transferred off of the mast (for example, through the upper tubular elevator and upper landing tool) so as to enable offline suspension (and optional cementing) of the tubular in the well. With one or more embodiment, when it is transferred off of the mast, it is transferred onto a tubular support structure. For example, as shown in  FIG. 3 , a tubular support structure, such as tubular support bridge  109  is disposed on ground  123  above cellar  111 . Tubular support bridge  109  may be sufficiently dimensioned to distribute the total supported weight of a given tubular string such that it distributes the weight on sufficient ground  123  area to avoid the collapse of the cellar  111 . A lower tubular slip or elevator  108  is disposed on the tubular support bridge  109  and may engage with the lower landing tool  107  or even with the upper portion of the tubular string  114 . Upon engagement of the lower tubular slip or elevator  108  with the lower landing tool  107 , the lower landing tool  107  may be disengaged from the upper landing tool  106 . Similarly, upper landing tool  106  and upper tubular elevator  103  may disengage from tubular string  114 . 
     Now referring to  FIG. 4 , the cementing of the well  122  shown in  FIG. 3  is shown. Thus, in one or more embodiments, the walking rig  121  is moving or has moved (as seen by the arrow  300 ) from the first well  122  to the second well  117 . The rig displacement may be feasible as the walking rig  121  is oriented in a direction parallel to the two wells  117  and  122  (and not perpendicular as shown for convenience in  FIG. 4 ). Thus, substructure  105  is now disposed on the ground  123  above the cellar  118  of the second well  117 . The lower landing tool  107  (disengaged from the upper landing tool  106 ), the wellhead  110 , and the tubular string  114  are within the first well  122 , and a cement head  301  is installed above the lower landing tool  107 . The tubular support bridge  109  disposed on the ground  123  above the cellar  111  of the first well  122  now supports a weight of the lower landing tool  107 , the tubular string  114 , optionally the wellhead  110 , and the cement head  301 . The tubular support structure, shown in this embodiment as the tubular support bridge  109 , ultimately bears the weight of the tubular string  114 , as well as other components in place to engage and cement the well. In this embodiment, the tubular string  114  is a surface casing, i.e., a tubular having a relatively large diameter that provides structural strength to the well for subsequent tubular strings to be suspended within the surface tubular string  114 . The length of the conductor string  113  is often short in comparison with the length of the surface tubular string  114 . Thus, most of the newly cemented section of the surface tubular string  114  is facing the new open hole  115  so that proper sealing and support of the surface tubular string  114  may be provided by this section of this open-hole  115 . 
     Furthermore, the lower landing tool  107  is disposed in between the wellhead  110  and cement head  301 , and engages with the tubular string  114  and the tubular slip or elevator  108 . Additionally, a small crane  303  may optionally be disposed on the tubular support bridge  109 . The small crane  303  may be used, for example, to assist in the installation of cement head  301  on the lower landing tool  107  or to hold a wireline spool (not shown) or aid in the lifting or support of any tools needed for any operation to the first well  122 . Once the cement job is ready to be performed, a plurality of cement lines  302  are attached to the cement head  301 . A cement slurry (not shown) is pumped through the plurality of cement lines  302  and through the cement head  301  and down through the tubular string  114  into the first well  122 . The cement slurry may be pumped into the first well  122 , down the inner diameter of the tubular string  114  and into the annulus created between the tubular string  114  and wellbore  115  according to conventional practices in the art for any cement job. After the cement is pumped downhole and displaced into the annulus, waiting on cement occurs prior to assessing whether the top of cement meets regulatory and safety requirements. In the event that any remedial cement jobs may need to be performed, they can be done at this time, including a top job using a small-diameter (macaroni) pipe (not shown) in the annulus or the tubular string  114  may be perforated to circulate cement into the annulus via these perforations (not shown). Following the completion of the cement job, the well may be secured, for example, by a flange (not shown) attached onto the wellhead  110 . A valve (not shown) may also be installed on the wellhead  110  side connection so that potential pressure may be bled before removing the flange when subsequent sections are to be drilled. Further, an additional pressure barrier may include a tubular float valve (not shown) or the cement may have been displaced with a fluid that has an adequate density to create an over-balance in the well. 
     As shown in  FIG. 5 , another embodiment of a system for preparation of offline suspension (and optional cementing) of a tubular in a top section of a well, i.e, a surface casing, is shown. Referring to  FIG. 5 , in one or more embodiments, the walking rig  121  is positioned on the first well  121 . A second well  117  is adjacent the first well  122 . Walking rig  121  includes a substructure  105  having a rig floor  104  and a mast  100  disposed on the rig floor  104 . The mast  100  has a traveling block  102  powered by a drawwork  101 , which is disposed on the rig floor  104 . In this embodiment, while mast  100  is centered over first well  122 , the substructure  105  extends over at least first well  122  and second well  117 . That is, substructure is disposed on a ground  123  above both the cellar  111  of the first well  122  and the cellar  118  of the second well  117 . In  FIG. 5 , the substructure  105  is shown to be perpendicular to the direction of the multiple cellars for ease in illustration. In common application, the substructures  105  would be parallel to that cellar direction. Such embodiments may be used, for example, when the cellar  111  of the first well  122  and the cellar  118  of the second well  117  are relatively closely spaced, such as by 6 feet apart, rather than being 20 feet apart. Thus, one of ordinary skill in the art will appreciate how the walking rig  121  can encompass both the first well  122  and the second well  117  to provide time saving operations. The walking rig  121  may move, for example, at a rate of 1 to 2 feet per minute; however such rate is not a limitation on the present disclosure. 
     As illustrated in  FIG. 5 , the upper landing tool  106  and the lower landing tool  107  are disengaged from one another; however, it may be understood that upper landing tool  106  and lower landing tool  107  may be used to place the surface tubular string  114  in the well. An upper tubular elevator  212 , connected to the traveling block  102  through an upper bail  200 , supports the upper landing tool  106 . As stated above, the tubular support structure is not limited to the tubular support bridge  109 , shown in  FIG. 3 . Rather,  FIG. 5  illustrates another example of a tubular support structure that may be used to suspend the weight of the tubular string independent of the rig such that the rig may move off the well during the suspension, cementing and waiting on cement, for example. 
     As illustrated in  FIG. 5 , one or more blowout preventer (BOP) winches  205  (a winch that is conventionally used to handle BOPs) is used as the tubular support structure. Specifically, one or more rails  201  are connected either to the rig floor  104  or to the substructure  105 . As previously mentioned, it is common that the substructures  105  are parallel to the direction defined by the multiple cellars  111 ,  118 . With such construction, the one or more rails  201  would also be parallel to the substructure. The rig of  FIG. 5  is represented with the one or more rails  201  and substructure  105  being perpendicular for convenience of illustration, but could be used as well. The one or more rails  201  (and the one or more winches  205 ) are laid on each side of a central hole  150  in the rig floor  104  (typically through the rotary table) to allow the passage of well tubular (drill-sting and casing). The one or more BOP winch  205  are disposed on the one or more rails  201 , and a plurality of winch wheels  202  allows the one or more BOP winches  205  to move along the one or more rails  201 . The plurality of winch wheels  202  may be any connection known in the art to allow an apparatus to move against another apparatus (i.e. tires and wheels). When the walking rig  121  moves, the plurality of winch wheels  202  may allow rig displacement while the one or more BOP winches  205  stays in its initial vertical position above the first well  122 . Additionally, a cable hook  203  extends from the one or more BOP winch  205  to engage with a lower bail  204 . The lower bail  204  connects to a lower tubular elevator  206 , which engages and supports the lower landing tool  107  (which, as mentioned above, has already been disengaged from upper landing tool  106  as illustrated in this system). In one or more embodiments, the elevator  206  may be hung on the one or more BOP winches  205  before the start of lowering the first tubular element of the tubular string  114 . During the procedure to lower the tubular string  114  into the well  122 , the tubular string  114  may slide in the bore of the elevator  206  hung onto the one or more BOP winches  205 . Once the tubular string  114  has reached the desired depth in the wellbore  115  thanks to the usage of the mast  100 , travelling block  102  and bails  200  and elevator  212 , the weight of the tubular string  114  may be transferred to the tubular elevator  206  hung on the winch  205 . Then the upper part of the running tool  106  can be decoupled from the lower part of the running tool  107  and lifted above the rig floor  104 . In such condition, the walking rig  121  may leave the first well  122 , and cementing of the tubular string  114  within the first well  122  may commence. In this embodiment, as walking rig  121  is moved from first well  122  to second well  117 , the tubular support structure (BOP winch  205  equipped with wheel  202 ) stays stationary with respect to the first well  122 , and thus does not move with walking rig  121 . As illustrated, however, the substructure  105  (on which the rail  201  supporting the BOP winch  205  is mounted) extends over both first well  122  and second well  117 . Thus, as walking rig  121  moves, substructure  105  (and thus rail  201  and BOP winch) may stay positioned over first well  122 . Also, the displacement of the rig  121  would be facilitated with substructures parallel to the direction of the multiple cellars. 
     Referring now to  FIG. 6 , another embodiment of a system for preparation of offline suspension (and optional cementing) of a tubular in a top section of a well, i.e, a surface casing, is shown. Referring to  FIG. 6 , in one or more embodiments, the walking rig  121  is positioned on the first well  121 . A second well  117  is adjacent the first well  122 . Walking rig  121  includes a substructure  105  having a rig floor  104  and a mast  100  disposed on the rig floor  104 . The mast  100  has a traveling block  102  powered by a drawwork  101 , which is disposed on the rig floor  104 . In this embodiment, while mast  100  is centered over first well  122 , the substructure  105  extends over at least first well  122  and second well  117 . That is, substructure is disposed on a floor  123  above both the cellar  111  of the first well  122  and the cellar  118  of the second well  117 . Such embodiments may be used, for example, when the cellar  111  of the first well  122  and the cellar  118  of the second well  117  are relatively closely spaced, such as by 6 feet apart, rather than being 20 feet apart. Thus, one of ordinary skill in the art will appreciate how the substructure  105  can encompass both the first well  122  and the second well  117  to provide time saving operations. The walking rig  121  may move, for example, at a rate of 1 to 2 feet per minute; however, such rate is not a limitation on the present disclosure. 
     As illustrated in  FIG. 6 , in one or more embodiments, a rolling bridge  207  is used as the tubular support structure. Specifically, a one or more rails  208  are attached to the substructure  105 . The one or more of rails  208  may be used to support the BOP wrangler (not shown) during the installation of the BOP above the well head  110  generally attached above the surface tubular string  114 . Rails  208  also support rolling bridge  207 . As shown by  FIG. 6 , a more conventional rig design of the rig as seen in line with the multiple cellars  111 ,  118 . In such view, it is more obvious to understand the location of the rails  208  attached to the substructure  105  (as well as the rails  201  attached below the rig floor  104 , as illustrated in  FIG. 3 ). In  FIG. 6 , the substructures  105  are parallel to the direction of the multiple cellars  111 ,  118 . Specifically, rolling bridge  207  has wheel  209  to connect and allow the rolling bridge  207  to move on the one or more rails  208 . The wheel  209  may be any connection known in the art to allow an apparatus to move against another apparatus (i.e. tires and wheels). Additionally, also disposed on rolling bridge  207  is the lower tubular elevator  206 , which engages and supports the lower landing tool  107 . In one or more embodiments, the elevator  206  may be supported by the rolling bridge  207  before the start of lowering the first tubular element of the tubular string  114 . During the procedure to lower the tubular string  114  into the well  122 , the tubular string  114  must slide in the bore of the elevator  206  supported by the rolling bridge  207 . Once the tubular string  114  has reached the desired depth in the wellbore  115  by the use of the mast  100 , travelling block  102  and bails  200  and elevator  212 , the weight of the tubular string  114  can be transferred to the tubular elevator  206  supported by the rolling bridge  207 . Then the upper part of the running tool  106  can be decoupled from the lower part of the running tool  107  and lifted above the rig floor  104 . 
     Still referring to  FIG. 6 , once the tubular string  114  has reached the desired depth in the wellbore  115 , and the weight of the tubular string  114  has been transferred to the tubular elevator  206 , the walking rig  121  may leave the first well  122 , and offline suspension of the tubular string  114  within the first well  122  may commence. When the tubular string  114  is to be cemented in place, the cement head (as shown in  FIG. 4 ) is installed on the lower part of the running tool  107 . Then the cement line (as shown in  FIG. 4 ) can be connected to the cement head (as shown in  FIG. 4 ). This means that these components are located below the rig floor. When the cement job is completed, the wellhead  110  may be ready for supporting any additional tubular string after the drilling of additional well sections. When using the wellhead  110  as shown in  FIG. 5 or 6 , such wellhead  110  is connected on top of the tubular string  114  and maintained in proper place during the cement job by the lower running tool  107  supported by the elevator  206 . In some other implementations, the wellhead  110  may have to be added after the placement and hardening (setting) of the cement. As the walking rig  121  may be moved to the other well  117  for its own drilling and construction, the first well  122  may be left unattended for some time. To insure proper protection of the well  122  during this period, the wellhead  110  may be covered with a flange. To allow proper monitoring of potential appearance of pressure inside the tubular string  114 , a valve  518  and line  512  (shown in  FIG. 8 ) may have to be added. With these additional equipment, pressure inside the tubular string can be monitored and bleeding can be performed. 
     In  FIG. 7 , in one or more embodiments, a top view of the rolling bridge  207  as the tubular support structure is shown. The rolling bridge  207  has an opening  400  to receive the tubular string  114 . Additionally, the one or more rails  208  are attached to the substructure  105 . The one or more of rails  208  may be used to support the BOP wrangler (not shown) during the installation of the BOP above the well head typically attached above the surface tubular string (not shown) and supports rolling bridge  207 . Rolling bridge  207  has wheel  209  to connect and allow the rolling bridge  207  to move on the one or more rails  208 . The wheel  209  may be any connection known in the art to allow an apparatus to move against another apparatus (i.e. tires and wheels, etc.). 
     Now referring to  FIG. 8 , in one or more embodiments, a view of the walking rig  121  parallel to the cellar  111  of the first well  122  is shown. A second well (not shown based on the orientation of the view) may be aligned with the direction of the cellar  111 , and the substructures  105  are parallel to that direction. Furthermore, the combination of the one or more BOP winches  205  and the rolling bridge  207  may be used to support the surface tubular string  114 . As described above, one or more rails  208  are attached to the substructure  105 . The one or more of rails  208  may be used to support the BOP wrangler (not shown) during the installation of the BOP above the well head  110  which is generally attached above the surface tubular string  114 . Rails  208  also support rolling bridge  207 . Additionally, the rolling bridge  207  has a wheel  209  to connect and allow the rolling bridge  207  to move on the one or more rails  208 . The wheel  209  may be any connection known in the art to allow an apparatus to move against another apparatus (i.e. tires and wheels). Additionally, also disposed on rolling bridge  207  is the lower tubular elevator  206 , which engages and supports the lower landing tool  107 . 
     Also shown in  FIG. 8  are one or more rails  201  connected either to the rig floor  104  or to the substructure  105 . The one or more rails  201  (and the one or more winches  205 ) are laid on each side of a central hole  150  in the rig floor  104  (typically through a rotary table) to allow the passage of well tubular (drill-sting and casing). The one or more BOP winches  205  are disposed on the one or more rails  201 , and a plurality of winch wheels  202  allows the one or more BOP winches  205  to move along the one or more rails  201 . The plurality of winch wheels  202  may be any connection known in the art to allow an apparatus to move against another apparatus (i.e. tires and wheels). 
     Now referring to  FIG. 9 , an embodiment of a system for the offline suspension (and optional cementing) of intermediate and/or production tubular is shown. In one or more embodiments, the walking rig  121  is positioned on the first well  122 . A second well (not shown) is adjacent the first well  122 : the second well may be shown as the view may be aligned with the direction of the multiple cellars, and the substructures  105  are parallel to that direction. Walking rig  121  includes a substructure  105  having a rig floor  104  and a mast  100  disposed on the rig floor  104 . The mast  100  has a traveling block  102  powered by a drawwork  101 , which is disposed on the rig floor  104 . An upper tubular elevator  212 , connected to the traveling block  102  through an upper bail  200 , supports an upper landing tool  533 . 
     As illustrated, a first tubular string  522  (which may, for example, be a surface tubular string such as that shown in  FIG. 3-6 or 8 ) is in the wellbore  115  of the first well  122  and secured therein by a cement section  521 . Wellhead  110  is attached to first tubular string  522 . Additionally, while walking rig  121  is positioned at the first well  122 , which has already had first tubular string  522  cemented in place, it is envisioned that the walking rig  121  did not necessarily remain in such position during the cementing, but may have been relocated to a second well (or any number of other wells) for drilling of their top sections prior to relocating back at first well  122  to ensure the continuation of the construction of the first well  122  (including the drilling of the open-hole  115 ). The wellhead  110  has been added during or after the installation the surface tubular string  522 . After the cement job of the surface tubular string  522 , the wellhead  110  can support the upper section of any additional tubular strings (i.e., second tubular string  523 ) via the proper usage of tubular slips, wedges or flanges. When the wellhead installation has been completed and the cement sheet hardened, the BOP  511  can then be installed on top of the wellhead  111 . The bell-nipple  508  and return-line  509  may be connected and disconnected from the BOP  511  at different stages of the well construction. The well  122  may be left secured by proper closing at its top. This can be achieved by leaving the BOP  511  with its blind rom closed on top the wellhead  110 . If the BOP  511  must be removed, a flange (not shown) may be installed on the wellhead  110 . Further, one skilled in the art would appreciate that the walking rig  121  can travel to a plurality of wells and is not constrained to traveling in any particular order. Further, while it is envisioned that the first tubular string  522  may have been cemented in place without the walking rig  121  being positioned at the first well  122  (such by the systems described above), it is also envisioned that first tubular string  522  may have been cemented in place using conventional means for supporting the tubular string, i.e., via the structure associated with walking rig  121 . 
     In one or more embodiments, BOP  511  is connected on top of the wellhead  110  by conventional means known in the art. It should be noted the BOP  511  may be added to the wellhead  110  at any time during the first well&#39;s  122  life. Furthermore, a bell nipple  508  with a return line  509  may be installed above the BOP  511 . The return line  509  is connected with a flow line  510 , which is in fluid communication with a plurality of trip tanks  514  and a mud tank  513 . A shaker  515  may receive returned mud from the return line  509  and perform solids removal prior to collection of the mud in the mud tank  513 . As seen in  FIG. 8 , a valve  518  with a line  512  is connected to the wellhead  110  to aid in pressure release. 
     A second tubular string  523  having an outer diameter smaller than the inner diameter of the first tubular string  522  is lowered by tubular elevator  212  and a landing joint (of an upper landing tool  533  and a lower landing tool  534 ) into the wellbore  115  of the first well  122  through the BOP  511  and bell nipple  508 . When the second tubular string  523  is at proper depth, a hanger  516  is added to the tubular string  523  to be landed in the spool of wellhead  110 . Then, the tubular string  523  and hanger  516  can be lowered through the usage of landing joint  533 ,  534  and landed into the wellhead  110  spool  519 . In one or more embodiments, the liner hanger  516  is a fluted hanger which comprises holes in the hanger to allow return flow. The second tubular string  523  has a plurality of tubular centralizers  524  disposed around the second tubular string&#39;s  523  outer diameter to aid in keeping the second tubular string  523  in a central position in the wellbore  115 . Furthermore, a plurality of float valves  525  may be at the bottom of the second tubular string  523 . 
     Once the hanger  516  is landed in the spool  519  of wellhead  110 , the weight of the second tubular string  523  can be transferred from the traveling block  102  onto the wellhead  110 . Once transferred, the second tubular string  523  is in tension from the hanger  516 . The upper landing tool  533  may be removed, and the return line  509  may be modified to allow for moving of substructure  105  and rig  121 . In embodiments involving cementing of second tubular string  523 , a cementing head (not shown) may be installed on the lower landing tool  534 , and cementing may commence while rig  121  is being moved or has been moved. In one or more embodiments, the cement head (not shown) is installed on top of the lower handling tool  534  above the bell-nipple  508  and also below the rig floor  104 . Furthermore, the bell-nipple  534  may be modified to potentially reduce its height. If all these conditions can be achieved while the walking rig  121  is still above the well  122 , the cement head can be installed before moving the walking rig  121 . In some case, the walking rig  121  may have to be moved first to allow such installation. In most cases, the return line  509  may be temporarily removed to allow the movement of the walking rig  121 . The return line  509  may be reconnected (at least for temporary operation) for the fluids displaced by the cement slurry, and the cement job may be performed. The displaced well fluids may flow through the return line  509  if a hanger  516  is fluted (allowing fluid flow therethrough) or the fluid may flow through the bleed line  512  and bleed valve  518 . In either case, the returned well fluid may be directed towards mud tanks  513  or trip tanks  514 . After waiting on cement (to cure), the cementing head and the landing joint are removed, and the BOP  511  shear rams may be closed to provide for a pressure containment barrier. The temporary return line  509  and bell nipple  508  may be removed, and a flange (not shown) may be added on top of the BOP  511  to ensure an additional pressure containment barrier. Additional pressure containment may include the float shoes. 
     After the primary cement job, cement logs may be performed. If a remedial job is required (either due to low top of cement or channels), conventional remediation methods may be performed if the new cement is pumped directly through the tubular string  532 . While conventional practices may involve the use of a drill pipe, because the rig  121  has been moved, a coiled tubing may be used instead. 
     Now referring to  FIG. 10 , an embodiment of a system for the offline suspension (and optional cementing) of intermediate and/or production tubular is shown to include reciprocation. The embodiment allows for the performance of tubular reciprocation when the walking rig  121  is not aligned with the well  122  after rig walking. As illustrated, a first tubular string  522  (which may, for example, be a surface tubular such as that shown in  FIG. 3-6 or 8 ) is cemented in place in the wellbore  115  of the first well  122 , and a second tubular string  523  has been lowered into the well  122  as described with respect to  FIG. 9 . The rig with its mast (not shown) used to drill and lower second tubular string  523  may be moved to a second well (not shown) once second tubular string  523  has reached the required depth for a cement job to be performed. While the weight of tubular string  523  was originally held by rig mast (not shown) through the tools described above, upon reaching the final depth, the weight of second tubular string  523  may be supported in the well  122  through a tubular support structure, such as a tubular support  604  that is below the rig floor  654 . Specifically, the weight of the tubular string  523  terminated upwards by the lower landing tool  534  is supported by the elevator  601 . The elevator  601  allows for the transfer of the weight of the tubular string  523  on the tubular support  604 . In this embodiment, a hook (not shown) or the rig  121  does not support the weight of the tubular string  523 , and the upper part of the landing tool (shown in  FIG. 9  as  533 ) may be removed. 
     Legs  613  of tubular support  604  are connected to a plurality of actuators  609 . The plurality of actuators  609  may be hydraulically powered or otherwise powered by any means know in the art to axially move the legs  613  and tubular support  604  to change the vertical position of the tubular support  604  on demand. The moving of the tubular support  604  will reciprocate the second tubular string  523  in an axial fashion as seen by a reciprocation arrow  620 . This reciprocation occurs by the engagement of second tubular string  523  by lower landing tool  534 , which is also engaged (supported by) with the tubular support  604 . Reciprocating the second tubular string  523  may aid in proper and even distribution of a cement slurry (not shown) being pumped into the wellbore  115 . Actuators  609  may be disposed on base boxes  611 , which rest on floor  123 . A support substructure  605 , which supports the rig floor  654 , is also disposed on the base boxes  611 , and a plurality of guides  603  are connected to the support substructure  605 . The plurality of guides  603  additionally connect to guide arms  614  extending from tubular support  604  to aid in keeping the plurality of actuators  609  running straight up and down and to moving through the desired range of axial positions to cause the tubular to reciprocate within the well  122 . It is envisioned that the actuators  609  may be the same actuators that may raise the rig floor (not shown) or other elements of the rig (not shown) once the rig has moved. In such an instance, an upper attachment designed to engage with the tubular support  604 /legs  613  may be used when switching between movement of the rig and the tubular support  604 . 
     Additionally, in one or more embodiments, a rotary table  602  may be disposed on the tubular support  604  and supports the elevator  601  which in turn support the lower landing tool  534  which support the tubular string  523 . With these supports, the rotary table  602  may rotate the second tubular string  523 , which is will allow for proper and even distribution through the annulus of a cement slurry (not shown) being pumped into the wellbore  115 , if needed. In the presence of the rotary table  602 , a slip or elevator  601  will be disposed on top of the rotary table  602 , and the slip or elevator  601  engage with the lower landing tool  534 . If the rotary table  602  is not present, the slip or elevator  601  will be disposed on top of the tubular support  604 , and the slip or elevator  601  engage with the lower landing tool  534 . Reciprocation and/or rotation of the tubular string  523  may be performed during the displacement of the cement slurry in the annulus. During “waiting on cement” reciprocation and rotation may be stopped. At the end of the slurry displacement, if the tubular string  523  is equipped with landing sleeves (or integrated slips), the reciprocating system may lower the tubular string  532  via the actuators  613  so that the landing sleeve  516  rests against the landing spool  519 . 
     Still referring to  FIG. 10 , in one or more embodiments, a cement head  600  is engaged with the lower landing tool  534  above the tubular support  604 . Furthermore a plurality of flexible lines or chiksans  612  are connected to the cement head  600  to pump a cement slurry (not shown) down into the wellbore  115 , such as by conventional means. In another embodiment, reciprocation of the tubular string  523  may be performed via the usage of BOP winches  205  when these winches  205  are used to support the tubular via a tubular elevator  206 , as shown in  FIG. 5 . 
     Furthermore, methods of the present disclosure may include use of the walking rig and other structures, such as in  FIGS. 1-10 . Because the method may apply to any of the embodiments, reference numbers are not referenced to avoid confusion of the numbering between the different embodiments. Initially, the walking rig supports a weight of the tubular slip or elevator, the lower landing tool, the wellhead, and the tubular string. Then the weight of the tubular slip or elevator, the lower landing tool, the wellhead, and the tubular string will be transferred from the walking rig to the tubular support structure. Once the weight of the tubular slip or elevator, the lower landing tool, the wellhead, and the tubular string is transferred over to the tubular support structure, the walking rig will move as seen by the arrow from the first well to the second well. When the walking rig has positioned off the first well, the cement head will be installed on top of the lower handling tool. The weight of casing, the landing nipple, the lower landing tool and the cement head is supported by the tubular support structure prior to commencing cementing, which may occur once the rig has positioned off the first well or even while it is still positioned over the first well. However, the tubular is supported without the assistance of the rig. Once the cement head is in position, pumping of the cement slurry through the tubular string and into an annulus between the tubular string and the wellbore may begin. The amount of cement slurry being pumped, through the tubular string and into an annulus between the tubular string and the wellbore, is predetermined based on the conditions of the first well and is well known to those skilled in the art. 
     While the invention has been described with respect to a limited number of embodiments, those skilled in the art, having benefit of this disclosure, will appreciate that other embodiments can be devised which do not depart from the scope of the invention as disclosed herein. Accordingly, the scope of the invention should be limited only by the attached claims.