Patent Publication Number: US-2023160278-A1

Title: Hydraulic fracturing plan and execution of same

Description:
CROSS-REFERENCE TO RELATED APPLICATIONS 
     This application is a continuation of U.S. patent application Ser. No. 17/878,493, filed Aug. 1, 2022, which is a continuation of U.S. patent application Ser. No. 17/388,716 (the “&#39;716 Application”), filed Jul. 29, 2021, now issued as U.S. Pat. No. 11,401,779, which claims the benefit of the filing date of, and priority to, U.S. Patent Application No. 63/189,663, filed May 17, 2021, the entire disclosures of which are hereby incorporated herein by reference. 
     The &#39;716 Application is a continuation-in-part (CIP) of U.S. patent application Ser. No. 17/319,854 (the “&#39;854 Application”), filed May 13, 2021, the entire disclosure of which is hereby incorporated herein by reference. 
     The &#39;854 Application is a continuation-in-part (CIP) of U.S. patent application Ser. No. 16/855,749 (the “&#39;749 Application”), filed Apr. 22, 2020, now issued as U.S. Pat. No. 11,480,027, the entire disclosure of which is hereby incorporated herein by reference. The &#39;749 Application claims the benefit of the filing date of, and priority to, U.S. Patent Application No. 62/836,761, filed Apr. 22, 2019, the entire disclosure of which is hereby incorporated herein by reference. 
     The &#39;749 Application is a continuation-in-part (CIP) of U.S. patent application Ser. No. 16/248,648 (the “&#39;648 Application”), filed Jan. 15, 2019, now issued as U.S. Pat. No. 10,724,682, the entire disclosure of which is hereby incorporated herein by reference. The &#39;648 Application claims the benefit of the filing date of, and priority to, U.S. Application No. 62/617,443, filed Jan. 15, 2018, the entire disclosure of which is hereby incorporated herein by reference. 
     The &#39;749 Application is also a CIP of U.S. patent application Ser. No. 16/803,156 (the “&#39;156 Application”), filed Feb. 27, 2020, now issued as U.S. Pat. No. 11,242,724, the entire disclosure of which is hereby incorporated herein by reference. The &#39;156 Application is a CIP of U.S. patent application Ser. No. 16/248,633 (the “&#39;633 Application”), filed Jan. 15, 2019, now issued as U.S. Pat. No. 10,584,552, the entire disclosure of which is hereby incorporated herein by reference. The &#39;633 Application claims the benefit of the filing date of, and priority to, U.S. Patent Application No. 62/617,438 (the “&#39;438 Application”), filed Jan. 15, 2018, the entire disclosure of which is hereby incorporated herein by reference. 
     The &#39;156 Application is also a CIP of U.S. patent application Ser. No. 16/436,623 (the “&#39;623 Application”), filed Jun. 10, 2019, now issued as U.S. Pat. No. 11,208,856, the entire disclosure of which is hereby incorporated herein by reference. The &#39;623 Application claims the benefit of the filing date of, and priority to, U.S. Patent Application No. 62/755,170, filed Nov. 2, 2018, the entire disclosure of which is hereby incorporated herein by reference. 
     The &#39;156 Application is also a CIP of U.S. patent application Ser. No. 16/100,741 (the “&#39;741 Application”), filed Aug. 10, 2018, now issued as U.S. Pat. No. 10,689,938, the entire disclosure of which is hereby incorporated herein by reference. The &#39;741 Application claims the benefit of the filing date of, and priority to, U.S. Patent Application No. 62/638,688, filed Mar. 5, 2018, U.S. Patent Application No. 62/638,681, filed Mar. 5, 2018, U.S. Patent Application No. 62/637,220, filed Mar. 1, 2018, U.S. Patent Application No. 62/637,215, filed Mar. 1, 2018, and U.S. Patent Application No. 62/598,914, filed Dec. 14, 2017, the entire disclosures of which are hereby incorporated herein by reference. 
     The &#39;749 Application is related to U.S. patent application Ser. No. 16/801,911, filed Feb. 26, 2020, the entire disclosure of which is hereby incorporated herein by reference. 
     The &#39;716 Application is also related to U.S. patent application Ser. No. 17/360,336, filed Jun. 28, 2021, the entire disclosure of which is hereby incorporated herein by reference. 
    
    
     BACKGROUND 
     This application relates generally to oil and gas hydraulic fracturing operations and, more particularly, to a hydraulic fracturing plan executable by a hydraulic fracturing system to hydraulically fracture a plurality of oil and gas wells. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
         FIG.  1 A  is a diagrammatic illustration of a hydraulic fracturing system operably to execute a hydraulic fracturing plan to hydraulically fracture a plurality of oil and gas wells, according to one or more embodiments. 
         FIG.  1 B  is a flow diagram illustrating a method for hydraulically fracturing a plurality of wells by executing a hydraulic fracturing plan using the hydraulic fracturing system of  FIG.  1 A , according to one or more embodiments. 
         FIG.  2 A  schematically illustrates execution of one or more sub-step(s) of a first step of the method illustrated in  FIG.  1 B , which first step is or includes equalizing a lubricator of a frac leg associated with a first well, and opening the first well, according to one or more embodiments. 
         FIG.  2 B  schematically illustrates execution of one or more additional sub-step(s) of the first step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  2 C  schematically illustrates execution of one or more additional sub-step(s) of the first step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  2 D  schematically illustrates execution of one or more additional sub-step(s) of the first step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  2 E  schematically illustrates execution of one or more additional sub-step(s) of the first step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  2 F  schematically illustrates execution of one or more additional sub-step(s) of the first step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  2 G  schematically illustrates execution of one or more additional sub-step(s) of the first step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  3    is a flow diagram illustrating the various sub-steps, illustrated schematically in  FIGS.  2 A and  2 G , of the first step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  4    is a flow diagram illustrating various sub-steps of a second step of the method illustrated in  FIG.  1 B , which second step is or includes perforating a stage of the first well using a wireline perforating system, according to one or more embodiments. 
         FIG.  5 A  schematically illustrates execution of one or more sub-step(s) of the second step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  5 B  schematically illustrates execution of one or more additional sub-step(s) of the second step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  5 C  schematically illustrates execution of one or more additional sub-step(s) of the second step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  6    is a flow diagram illustrating various sub-steps of a third step of the method illustrated in  FIG.  1 B , which third step is or includes closing the first well using a valve apparatus, and draining a lubricator, according to one or more embodiments. 
         FIG.  7 A  schematically illustrates execution of one or more sub-step(s) of the third step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  7 B  schematically illustrates execution of one or more additional sub-step(s) of the third step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  7 C  schematically illustrates execution of one or more additional sub-step(s) of the third step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  7 D  schematically illustrates execution of one or more additional sub-step(s) of the third step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  7 E  schematically illustrates execution of one or more additional sub-step(s) of the third step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  7 F  schematically illustrates execution of one or more additional sub-step(s) of the third step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  7 G  schematically illustrates execution of one or more additional sub-step(s) of the third step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  7 H  schematically illustrates execution of one or more additional sub-step(s) of the third step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  7 I  schematically illustrates execution of one or more additional sub-step(s) of the third step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  8    is a flow diagram illustrating various sub-steps of a fourth step of the method illustrated in  FIG.  1 B , which fourth step is or includes isolating a stage of a second well in preparation for a hydraulic fracturing operation, according to one or more embodiments. 
         FIG.  9 A  schematically illustrates execution of one or more sub-step(s) of the fourth step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  9 B  schematically illustrates execution of one or more additional sub-step(s) of the fourth step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  9 C  schematically illustrates execution of one or more additional sub-step(s) of the fourth step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  9 D  schematically illustrates execution of one or more additional sub-step(s) of the fourth step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  9 E  schematically illustrates execution of one or more additional sub-step(s) of the fourth step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  9 F  schematically illustrates execution of one or more additional sub-step(s) of the fourth step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  9 G  schematically illustrates execution of one or more additional sub-step(s) of the fourth step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  10    is a flow diagram illustrating various sub-steps of a fifth step of the method illustrated in  FIG.  1 B , which fifth step is or includes detecting or otherwise determining that a fracturing stage of a third well has ended, according to one or more embodiments. 
         FIG.  11    schematically illustrates execution of one or more subs-step(s) of the fifth step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  12    is a flow diagram illustrating various sub-steps of a sixth step of the method illustrated in  FIG.  1 B , which sixth step is or includes determining whether to permit a regular swap or a continuous pumping swap (or “CP swap”), according to one or more embodiments. 
         FIG.  13    is a flow diagram illustrating various sub-steps of a seventh step of the method illustrated in  FIG.  1 B , which seventh step is or includes the regular swap from hydraulically fracturing the third well to hydraulically fracturing the second well, according to one or more embodiments. 
         FIG.  14 A  schematically illustrates execution of one or more sub-step(s) of the seventh step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  14 B  schematically illustrates execution of one or more additional sub-step(s) of the seventh step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  15    is a flow diagram illustrating various sub-steps of an eighth step of the method illustrated in  FIG.  1 B , which eighth step is or includes the CP swap from hydraulically fracturing the third well to hydraulically fracturing the second well, according to one or more embodiments. 
         FIG.  16 A  schematically illustrates execution of one or more sub-step(s) of the eighth step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  16 B  schematically illustrates execution of one or more additional sub-step(s) of the eighth step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  16 C  schematically illustrates execution of one or more additional sub-step(s) of the eighth step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  16 D  is a chart illustrating execution of one or more of the various sub-steps, schematically illustrated in  FIGS.  16 A through  16 C , of the eighth step of the method illustrated in  FIGS.  1 B , according to one or more embodiments. 
         FIG.  16 E  is another chart illustrating execution of one or more of the various sub-steps, schematically illustrated in  FIGS.  16 A through  16 C , of the eighth step of the method illustrated in  FIGS.  1 B , according to one or more embodiments. 
         FIG.  17    is a flow diagram illustrating various sub-steps of a ninth step of the method illustrated in  FIG.  1 B , which ninth step is or includes latching, filling, and pressure testing a frac leg associated with a fourth well in preparation for perforating a stage of the fourth well using the wireline perforating system, according to one or more embodiments. 
         FIG.  18 A  schematically illustrates execution of one or more sub-step(s) of the ninth step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  18 B  schematically illustrates execution of one or more additional sub-step(s) of the ninth step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  18 C  schematically illustrates execution of one or more additional sub-step(s) of the ninth step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  18 D  schematically illustrates execution of one or more additional sub-step(s) of the ninth step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  18 E  schematically illustrates execution of one or more additional sub-step(s) of the ninth step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  18 F  schematically illustrates execution of one or more additional sub-step(s) of the ninth step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  18 G  schematically illustrates execution of one or more additional sub-step(s) of the ninth step of the method illustrated in  FIG.  1 B , according to one or more embodiments. 
         FIG.  19 A  is a flow diagram illustrating a portion of another method for fracturing wells using the fracturing system of  FIG.  1 A , which another method includes swapping from simultaneously fracturing first and second wells to simultaneously fracturing third and fourth wells, according to one or more embodiments. 
         FIG.  19 B  is a flow diagram illustrating another portion of the another method of  FIG.  20 A , according to one or more embodiments. 
         FIG.  20    is a diagrammatic illustration of a computing node for implementing one or more embodiments of the present disclosure. 
     
    
    
     DETAILED DESCRIPTION 
     Referring to  FIG.  1 A , in an embodiment, a hydraulic fracturing system  100  for executing a hydraulic fracturing plan to hydraulically fracture wells  105 A through  105 C+n is illustrated, which hydraulic fracturing system  100  includes: a blender  110  adapted to mix fluid from a fluid source  115  with sand from a sand source  120  to produce hydraulic fracturing fluid; a suction manifold  125  adapted to receive the hydraulic fracturing fluid from the blender  110 ; a discharge manifold  130 ; a plurality of swap stations  135 , each adapted to communicate the hydraulic fracturing fluid from the suction manifold  125  to a corresponding pump truck  140 , and, after pressurization by the corresponding pump truck  140 , to communicate the pressurized hydraulic fracturing fluid from the corresponding pump truck  140  to the discharge manifold  130 ; and a zipper manifold  145  adapted to communicate the pressurized hydraulic fracturing fluid from the discharge manifold  130  to a plurality of hydraulic fracturing legs (or “frac legs”)  150 A through  150 C+n, each of which is adapted to communicate the pressurized hydraulic fracturing fluid from the zipper manifold  145  to a corresponding one of the wells  105 A through  105 C+n. In one or more embodiments, each of the swap stations  135  is or includes one or more components shown and described in U.S. patent application Ser. No. 16/436,189, filed Jun. 10, 2019, now published as U.S. Patent Application Publication No. 2020/0386359, the entire disclosure of which is hereby incorporated herein by reference. 
     A grease system  155  is adapted to communicate lubricating grease to various components of the frac legs  150 A through  150 C+n, including, for example, pump-down valves  160   a - b , master valves  165   a - b , and zipper valves  170   a - b  associated with each of the frac legs  150 A through  150 C+n (which components are shown in  FIGS.  2 A-G ,  5 A-C,  7 A-I,  9 A-G,  11 ,  14 A-B,  16 A-C, and  18 A-G). In one or more embodiments, the grease system  155  is or includes one or more components shown and described in U.S. patent application Ser. No. 16/248,648, filed Jan. 15, 2019 bearing Attorney Docket No. 57959.3US01, now issued as U.S. Pat. No. 10,724,682, the entire disclosure of which is hereby incorporated herein by reference. In addition, or instead, in one or more embodiments, the grease system  155  is or includes one or more components shown and described in U.S. patent application Ser. No. 16/938,341, filed Jul. 24, 2020 bearing Attorney 2020/0355322, the entire disclosure of which is hereby incorporated herein by reference in its entirety. In addition, or instead, in one or more embodiments, the grease system  155  is or includes one or more components shown and described in the &#39;749 Application, filed Apr. 22, 2020 bearing Attorney Docket No. 57959.5US01, now published as U.S. Patent Application Publication No. 2020/0248529, the entire disclosure of which is hereby incorporated herein by reference in its entirety. In addition, or instead, in one or more embodiments, the grease system  155  is or includes one or more components shown and described in the &#39;854 Application, filed May 13, 2021 bearing Attorney Docket No. 57959.11US01, the entire disclosure of which is hereby incorporated herein by reference in its entirety. 
     A controller  156  is adapted to control the grease system  155 , the frac legs  150 A through  150 C+n, or both. In one or more embodiments, the controller  156  is or includes a non-transitory computer readable medium and one or more processors adapted to execute instructions stored on the non-transitory computer readable medium. In one or more embodiments, the controller  156  is located on-site at the well site. Alternatively, the controller  156  may be located remotely from the well site. In one or more embodiments, the controller  156  includes a plurality of controllers. In one or more embodiments, the controller  156  includes a plurality of controllers, with one or more controllers located on-site at the well site and/or one or more other controllers located remotely from the well site. 
     Referring to  FIG.  1 B , in an embodiment, a method  175  for hydraulically fracturing the wells  105 A through  105 C+n by executing a hydraulic fracturing plan using the hydraulic fracturing system  100  of  FIG.  1 A  is illustrated. The method  175  generally includes: at step(s)  176   a , perforating a stage of each well using, for example, a wireline perforating system  177 ; at step(s)  176   b , isolating the perforated stage of each well using an object dropped, for example, from a launcher  178  of the wireline perforating system  177 ; and, at step(s)  176   c , hydraulically fracturing the isolated/perforated stage of each well. More particularly, as will be described in further detail below, the method  175  includes: at a step  225 , equalizing a lubricator  220  of the frac leg  150 A associated with the well  105 A, and opening the well  105 A; at a step  230 , perforating a stage of the well  105 A using the wireline perforating system  177 ; at a step  235 , closing the well  105 A using the valve apparatus  210  and draining the lubricator  220 ; at a step  238   a , queuing the well  105 A (as indicated at queue position n 2 ) in a frac queue  239  in preparation for a hydraulic fracturing operation; at a step  238   b , dequeuing the well  105 B (as indicated at queue position n 1 +1) from the frac queue  239  in preparation for the hydraulic fracturing operation; at a step  240 , isolating a stage of the well  105 B in preparation for the hydraulic fracturing operation; at a step  245 , detecting or otherwise determining that a fracturing stage of the well  105 D has ended; at a step  250 , determining whether to permit a regular swap or a CP swap from hydraulically fracturing (at a step  262 ) the well  105 D to hydraulically fracturing (at the step  262 ) the well  105 B; at a step  255 , executing the regular swap from hydraulically fracturing (at the step  262 ) the well  105 D to hydraulically fracturing (at the step  262 ) the well  105 B, or, at a step  260 , executing the CP swap from hydraulically fracturing (at the step  262 ) the well  105 D to hydraulically fracturing (at the step  262 ) the well  105 B; at the step  262 , hydraulically fracturing the well  105 B; optionally, at a step  263   a , queuing the well  105 D (as indicated at queue position n 1 ) in a wireline queue  264  in preparation for perforating a next stage of the well  105 D; optionally, at a step  238   b , dequeuing the well  105 E (as indicated at queue position  1 ) from the wireline queue  264  in preparation for perforating a next stage of the well  105 E; and, at a step  265 , latching, filling, and pressure testing the frac leg  150 E associated with the well  105 E. 
     In one or more embodiments, the controller  156  is adapted to control the grease system  155 , the frac legs  150 A through  150 C+n, or both, in order to execute the method  175  described herein. In one or more embodiments, the frac queue  239  and the wireline queue  264  are stored on a non-transitory computer readable medium that includes or is part of, for example, the controller  156 . In one or more embodiments, the frac queue  239  is or includes a list of data items, commands, etc., stored on the computer readable medium so as to be retrievable by one or more processors in a definite order (but not necessarily in the order stored), and the frac queue  239  is associated with the wells  105 A through  105 C+n, as shown in  FIG.  1 B . In addition, or instead, the frac queue  239  can be at least partially populated by an external source, such as, for example, the frac operator. Likewise, in one or more embodiments, the wireline queue  264  is or includes a list of data items, commands, etc., stored on the computer readable medium so as to be retrievable by one or more processors in a definite order (but not necessarily in the order stored), and the wireline queue  264  is associated with the wells  105 A through  105 C+n, as shown in  FIG.  1 B . In addition, or instead, the wireline queue  264  can be at least partially populated by an external source, such as, for example, the wireline operator. 
     Referring to  FIGS.  2 A through  2 G , in an embodiment, the frac leg  150 A associated with the well  105 A is illustrated, which frac leg  150 A includes: a wellhead including the master valves  165   a - b  (such as, for example, gate valves) operably coupled to, and adapted to be in fluid communication with, the well  105 A, each of the master valves  165   a - b  including associated grease ports (or “GPs”)  185   a - b ; the pump-down valves  160   a - b  (such as, for example, gate valves) operably coupled to, and adapted communicate fluid between, a pump-down truck  190  and the well  105 A, via the master valves  165   a - b , each of the pump-down valves  160   a - b  including an associated GP  195 ; and the zipper valves  170   a - b  (such as, for example, gate valves) operably coupled to, and adapted communicate fluid between, the zipper manifold  145  and the well  105 A, via the master valves  165   a - b , each of the zipper valves  170   a - b  including associated GPs  200   a - b . In one or more embodiments, one or both of the zipper valves  170   a - b  of each of the frac legs  150 A through  150 C+n include(s), or is/are part of, the zipper manifold  145 . In one or more embodiments, as in  FIGS.  2 A through  2 G , the frac leg  150 A associated with the well  105 A also includes a flow block  205  to which the pump-down valves  160   a - b  and the zipper valves  170   a - b  are operably coupled. 
     The frac leg  150 A associated with the well  105 A further includes a valve apparatus  210  via which both the wireline perforating system  177  and the object launched from, for example, the launcher  178 , are permitted entry to the well  105 A. The valve apparatus  210  includes: a containment area  215   a  (labeled “WELL”) adapted to be in fluid communication with the well  105 A via the master valves  165   a - b ; a containment area  215   b  (labeled “LUB”) adapted to be in fluid communication with the lubricator  220  of the wireline perforating system  177 ; and a containment area  215   c  (labeled “LL”) adapted to be in fluid communication with the containment area  215   a  via a flow control device  221   a  (e.g., a flapper-type flow control device), and adapted to be in fluid communication with the containment area  215   b  via a flow control device  221   b  (e.g., a flapper-type flow control device). 
     An equalization (“EQ”) valve  222   a  is connected between the containment areas  215   a  and  215   c , which EQ valve  222   a  is openable to permit pressure equalization between the containment areas  215   a  and  215   c  when the flow control device  221   a  is closed. Likewise, an equalization valve  222   b  is connected between the containment areas  215   b  and  215   c , which EQ valve  222   b  is openable to permit pressure equalization between the containment areas  215   b  and  215   c  when the flow control device  221   b  is closed. Additionally, an EQ valve  222   c  is connected between the lubricator  220  and atmosphere (labeled “ATM”), which EQ valve  222   c  permits pressure equalization between the lubricator  220  and atmosphere. A drain  223  is connected between a latch  234  (via which the lubricator  220  is detachably couplable to the valve apparatus  210 ) and a pump station  224   a , via which drain  223  fluid is communicable to and/or from the lubricator  220 , using, for example, an auto-fill/auto-drain pump of the pump station  224   a , when the lubricator  220  is connected to the valve apparatus  210  via the latch  234 . Finally, when the lubricator  220  is connected to the valve apparatus  210  via the latch  234 , fluid can also be communicated to the lubricator  220  (via, for example, the containment area  215   c  and the EQ valve  222   b ) using one or more boost pump(s)  224   b  in order to increase a fluid pressure in the lubricator  220 , aiding in pressure equalization between the lubricator  220  and the associated wellhead. For example, the boost pump(s)  224   b  may include: a first boost pump capable of pumping at relatively higher volumes and relatively lower pressures; and a second boost pump capable of pumping at relatively lower volumes and relatively higher pressures. The first and second boost pumps are used in combination to achieve combined pumping at relatively higher volumes and relatively higher pressures. In addition, or instead, a third boost pump capable of pumping at relatively higher volumes and relatively higher pressures may be used. Moreover, although shown as being connected to, and in fluid communication with, the containment area  215   c , one or more of the boost pump(s)  224   b  may instead be, include, or be part of the pump station  224   a.    
     In one or more embodiments, the valve apparatus  210  is or includes one or more components shown and described in U.S. patent application Ser. No. 15/487,785, filed Apr. 14, 2017, now issued as U.S. Pat. No. 10,662,740, the entire disclosure of which is hereby incorporated herein by reference. In addition, or instead, in one or more embodiments, the valve apparatus  210  is or includes one or more components shown and described in U.S. patent application Ser. No. 16/721,203, filed Dec. 19, 2019, now published as U.S. Patent Application Publication No. 2020/0123876, the entire disclosure of which is hereby incorporated herein by reference. 
     In one or more embodiments, the launcher  178  is or includes one or more components shown and described in U.S. patent application Ser. No. 16/248,633, filed Jan. 15, 2019 bearing Attorney Docket No. 57959.4US01, now issued as U.S. Pat. No. 10,584,552, the entire disclosure of which is hereby incorporated herein by reference. In addition, or instead, in one or more embodiments, the launcher  178  is or includes one or more components shown and described in U.S. patent application Ser. No. 16/801,911, filed Feb. 26, 2020 bearing Attorney Docket No. 57959.4US02, now published as U.S. Patent Application Publication No. 2020/0190933, the entire disclosure of which is hereby incorporated herein by reference. In addition, or instead, in one or more embodiments, the launcher  178  is or includes one or more components shown and described in U.S. patent application Ser. No. 16/803,156, filed Feb. 27, 2020 bearing Attorney Docket No. 57959.8US01, now published as U.S. Patent Application Publication No. 2020/0190934, the entire disclosure of which is hereby incorporated herein by reference. 
     In one or more embodiments, the frac legs  150 B through  150 C+n associated with each of the wells  105 B through  105 C+n, respectively, are substantially identical to the frac leg  150 A associated with the well  105 A; therefore, the frac legs  150 B through  150 C+n associated with each of the wells  1056  through  105 C+n will not be described in further detail. Accordingly, each of the frac legs  150 B through  150 C+n associated with the wells  105 B through  105 C+n includes features/components substantially identical to corresponding features/components of the frac leg  150 A associated with the well  105 A, which substantially identical features/components are given the same reference numerals and will also not be described in further detail. 
     Referring to  FIG.  3   , with continuing reference to  FIGS.  2 A through  2 G , in an embodiment, various sub-steps  226   a - h  of the step  225  of the method  175  illustrated in  FIG.  1 B  are shown in detail, which step  225  is or includes equalizing the lubricator  220  of the frac leg  150 A associated with the well  105 A, and opening the well  105 A. In one or more embodiments, the lubricator  220  is or includes one or more components shown and described in the &#39;749 Application. In addition, or instead, in one or more embodiments, the lubricator  220  is or includes one or more components shown and described in the &#39;854 Application. 
     At the sub-step  226   a , the boost pump(s)  224   b  is/are turned on to increase a fluid pressure in the lubricator  220  of the frac leg  150 A, thereby aiding in pressure equalization between said lubricator  220  and the well  105 A, as shown in  FIGS.  2 A and  3    (indicated by arrow  232   a  in  FIG.  2 A ). As shown in  FIG.  1 B , the step  265  of latching, filling, and pressure testing the frac leg  150 A associated with the well  105 A is executed on the frac leg  150 A just prior to the execution of the sub-step  226   a  on the frac leg  150 A. The step  265  will be described in further detail below as executed on the frac leg  150 E; however, the description below also applies to the execution of the step  265  on the frac leg  150 A. As a result, in one or more embodiments, just prior to execution of the sub-step  226   a  on the frac leg  150 A: the EQ valve  222   c  is closed; the drain  223  is closed; the lubricator  220  extends within, and is latched to, the latch  234 ; the flow control device  221   b  is closed; the EQ valve  222   b  is open; the flow control device  221   a  is closed; the EQ valve  222   a  is closed; the pump-down valves  160   a - b  closed, and grease from the grease system  155  is withheld from the corresponding GPs  195 ; the zipper valves  170   a - b  are closed, and grease from the grease system  155  is withheld from the corresponding GPs  200   a - b ; and the master valves  165   a - b  are open, and grease from the grease system  155  is communicated to the corresponding GPs  185   a - b . The communication of grease from the grease system  155  to the corresponding GPs  185   a - b  is not indicated by arrows in  FIG.  2 A  but is instead indicated by a lack of shading of the GPs  185   a - b  as shown in FIG.  2 A; the same lack of shading indication applies to the GPs  185   a - b  as shown in  FIGS.  2 B-G ,  5 A-C,  7 A-I,  9 A-G,  11 ,  14 A-B,  16 A-C, and  18 A-G. 
     At the sub-step  226   b , respective fluid pressures within the containment areas  215   a  and  215   c  are compared to determine whether the fluid pressure in the lubricator  220  of the frac leg  150 A has been equalized to within a threshold amount of the fluid pressure in the well  105 A. If it is determined that the fluid pressure in the lubricator  220  of the frac leg  150 A has not been equalized to within the threshold amount of the fluid pressure in the well  105 A, the EQ valve  222   a  is opened at the sub-step  226   c  to further encourage such pressure equalization between said lubricator  220  and the well  105 A, as shown in  FIGS.  2 B and  3   . Alternatively, the order in which the sub-steps  226   a  and  226   c  are executed may be reversed, or one of the sub-steps  226   a  and  226   c  may be omitted altogether. 
     At the sub-step  226   d , once it is determined that the fluid pressure in the lubricator  220  of the frac leg  150 A has been equalized to within the threshold amount of the fluid pressure in the well  105 A, the flow control device  221   a  is opened, as shown in  FIGS.  2 C and  3   . At the sub-step  226   e , the EQ valve  222   a  is closed, as shown in  FIGS.  2 D and  3   . However, in those embodiments in which the sub-step  226   c  of opening the EQ valve  222   a  is omitted, the sub-step  226   e  of closing the EQ valve  222   a  is also omitted. Additionally, the sub-step  226   e  may be executed to close the EQ valve  222   a  at any time before, during, or after, execution of the sub-steps  226   d ,  226   f , or  226   g . At the sub-step  226   f , the flow control device  221   b  is opened, as shown in  FIGS.  2 E and  3   . At the sub-step  226   g , the boost pump(s)  224   b  is/are turned off, as shown in  FIGS.  2 F and  3   . At the sub-step  226   h , the EQ valve  222   b  is closed, as shown in  FIGS.  2 G and  3   . Once the sub-steps  226   a - h  are executed, the well  105 A is ready for execution of the step  230 , namely perforating a stage of the well  105 A using the wireline perforating system  177 , as will be described in detail below in connection with  FIGS.  4  and  5 A through  5 C . 
     Referring to  FIGS.  4  and  5 A through  5 C , in an embodiment, various sub-steps  231   a - h  of the step  230  of the method  175  illustrated in  FIG.  1 B  are shown in detail, which step  230  is or includes perforating a stage of the well  105 A using the wireline perforating system  177 . In one or more embodiments, the wireline perforating system  177  is or includes the pump-down truck  190 , a wireline truck  233 , the lubricator  220 , the launcher  178 , the latch  234  (via which the lubricator  220  is detachably couplable to the valve apparatus  210 ), or any combination thereof. In addition, or instead, the wireline perforating system  177  may be or include one or more components shown and described in the &#39;749 Application. In addition, or instead, in one or more embodiments, the wireline perforating system  177  may be or include one or more components shown and described in the &#39;854 Application. 
     At the sub-step  231   a , a plug and perforating gun(s) are deployed from the lubricator  220 , as shown in  FIGS.  4  and  5 A  (indicated by arrow  232   b  in  FIG.  5 A ). At the sub-step  231   b , the pump-down valves  160   a - b  are opened, as shown in  FIGS.  4  and  5 B . At the sub-step  231   c , grease from the grease system  155  is communicated to the corresponding GPs  195  of the pump-down valves  160   a - b , respectively, as shown in  FIGS.  4  and  5 B  (indicated by arrows  232   c  in  FIG.  5 B ). At the sub-step  231   d , the plug and perforating gun(s) are pumped down into the well  105 A using the pump-down truck  190 , as shown in  FIGS.  4  and  5 B  (indicated by arrows  232   d  and  232   e  in  FIG.  5 B ). At the sub-step  231   e , the pump-down valves  160   a - b  are closed, and grease from the grease system  155  is withheld from the corresponding GPs  195 , as shown in  FIGS.  4  and  5 C . Additionally, the sub-step  231   e  may be executed to close the pump-down valves  160   a - b  at any time before, during, or after, execution of the sub-steps  231   f ,  231   g , or  231   h . At the sub-step  231   f , the plug is set in the well  105 A, as shown in  FIG.  4   . At the sub-step  231   g , the perforating gun(s) are detonated in the well  105 A, as shown in  FIG.  4   . Finally, at the sub-step  231   h , the spent perforating gun(s) are retrieved from the well  105 A, as shown in  FIGS.  4  and  5 C  (indicated by arrows  232   f  and  232   g  in  FIG.  5 C ). Once the sub-steps  231   a - h  are executed, the well  105 A is ready for execution of the step  235 , namely closing the well  105 A using the valve apparatus  210  and draining the lubricator  220 , as will be described in detail below in connection with  FIGS.  6  and  7 A through  7 I . 
     Referring to  FIGS.  6  and  7 A through  7 I , in an embodiment, various sub-steps  236   a - n  of the step  235  of the method  175  illustrated in  FIG.  1 B  are shown in detail, which step  235  is or includes closing the well  105 A using the valve apparatus  210  and draining the lubricator  220 . At the sub-step  236   a , bump up of the retrieved spent perforating gun(s) within the lubricator  220  is determined and/or confirmed. The sub-step  236   a  can be achieved in several ways, including, but not limited to: prompting the wireline operation for bump up; checking with the wireline operator to determine whether bump up has occurred; detecting bump up using a switch (e.g., a proximity switch) and/or another sensor (e.g., an accelerometer, a wireline speed sensor, a wireline tension sensor, a wireline length sensor, a wireline direction sensor, the like, or any combination thereof) associated with the lubricator  220 ; receiving verbal confirmation that bump up has occurred; or any combination thereof. 
     At the sub-step  236   b , once the bump up of the retrieved spent perforating gun(s) within the lubricator  220  is determined and/or confirmed, the flow control device  221   b  is closed, as shown in  FIGS.  6  and  7 A . At the sub-step  236   c , the flow control device  221   a  is closed, as shown in  FIGS.  6  and  7 B . At the sub-step  236   d , the EQ valve  222   c  is opened, as shown in  FIGS.  6  and  7 C , to bleed down a fluid pressure in the lubricator  220  (indicated by arrow  232   g  in  FIG.  7 C ). At the sub-step  236   e , the EQ valve  222   b  is opened, as shown in  FIGS.  6  and  7 D . At the sub-step  236   f , the lubricator  220  is checked to determine whether the fluid pressure in the lubricator  220  has dropped (or “bled down”) to below a threshold value (e.g., a bleed PSI limit), as shown in  FIG.  6   . At the sub-step  236   g , once it has been determined that the fluid pressure in the lubricator  220  has dropped to below the threshold value, the EQ valve  222   b  is closed, as shown in  FIGS.  6  and  7 E . 
     At the sub-step  236   h , the drain  223  is opened, as shown in  FIGS.  6  and  7 F . At the sub-step  236   i , the auto-drain pump of the pump station  224   a  is turned on to drain fluid from the lubricator  220  via the drain  223 , as shown in  FIGS.  6  and  7 F  (indicated by arrow  232   h  in  FIG.  7 F ). At the sub-step  236   j , the auto-drain pump is allowed to finish auto-draining the lubricator  220  before the drain  223  is closed, as shown in  FIGS.  6  and  7 G . At the sub-step  236   k , the latch  234  is unlatched, as shown in  FIGS.  6  and  7 G . At the sub-step  236   l , the lubricator  220  is removed, as shown in  FIGS.  6  and  7 H  (indicated by arrow  232   i  in  FIG.  7 H ). At the sub-step  236   m , the EQ valve  222   c  is closed, as shown in  FIG.  7 I . Finally, at the sub-step  236   n , an object drop (e.g., from the launcher  178 ) and/or a pressure test is/are enabled, as shown in  FIG.  6   . More particularly, once the sub-steps  236   a - n  are executed, the well  105 A is ready for execution of the step  240 , namely isolating a stage of the well  105 A in preparation for a hydraulic fracturing operation. The step  240  will be described in further detail below (in connection with  FIGS.  8  and  9 A through  9 G ) as executed on the frac leg  150 B to isolate a stage of the well  105 B; however, the description below also applies to the execution of the step  240  on the frac leg  150 A to isolate a stage of the well  105 A. 
     Referring to  FIGS.  8  and  9 A through  9 G , in an embodiment, various sub-steps  241   a - o  of the step  240  of the method  175  illustrated in  FIG.  1 B  are shown in detail, which step  240  is or includes isolating a stage of the well  105 B in preparation for a hydraulic fracturing operation. In one or more embodiments, the step  240  that is or includes isolating the stage of the well  105 B includes or is part of a hydraulic fracturing operation. At the sub-step  241   a , the EQ valve  222   b  is opened to facilitate pressure equalization between the containment areas  215   b  and  215   c , as shown in  FIGS.  8  and  9 A . At the sub-step  241   b , an object is dropped from the launcher  178 , as shown in  FIGS.  8  and  9 A . At the sub-step  241   c , respective fluid pressures within the containment areas  215   b  and  215   c  are checked to determine whether the containment areas  215   b  and  215   c  have been pressure equalized to within a threshold amount, as shown in  FIG.  8   . At the sub-step  241   d , once it is determined that the containment areas  215   b  and  215   c  have been pressure equalized to within the threshold amount, the flow control device  221   b  is opened, as shown in  FIGS.  8  and  9 B . At the sub-step  241   e , the object passes into the containment area  215   c , as shown in  FIGS.  8  and  9 C . At the sub-step  241   f , the flow control device  221   b  is closed, as shown in  FIGS.  8  and  9 C . At the sub-step  241   g , the EQ valve  222   b  is closed, as shown in  FIGS.  8  and  9 D . 
     At the sub-step  241   h , the boost pump(s)  224   b  is/are turned on to increase a fluid pressure in the containment area  215   c , thereby aiding in pressure equalization between the containment areas  215   a  and  215   c , as shown in  FIGS.  8  and  9 D  (indicated by arrow  232   j  in  FIG.  9 D ). At the sub-step  241   i , respective fluid pressures within the containment areas  215   a  and  215   c  are compared to determine whether the fluid pressure in the containment area  215   c  has been equalized to within a threshold amount of the fluid pressure in the well  105 B. If it is determined that the fluid pressure in the containment area  215   c  has not been equalized to within the threshold amount of the fluid pressure in the well  105 B, the EQ valve  222   a  is opened at the sub-step  241   j  to further encourage such pressure equalization between said containment area  215   c  and the well  105 B, as shown in  FIGS.  8  and  9 E . Alternatively, the order in which the sub-steps  241   h  and  241   j  are executed may be reversed, or one of the sub-steps  241   h  and  241   j  may be omitted altogether. 
     At the sub-step  241   k , once it is determined that the fluid pressure in the containment area  215   c  has been equalized to within the threshold amount of the fluid pressure in the well  105 B, the flow control device  221   a  is opened, as shown in  FIGS.  8  and  9 F . At the sub-step  241   l , the boost pump(s)  224   b  is/are turned off, as shown in  FIGS.  8  and  9 F . At the sub-step  241   m , the EQ valve  222   a  is closed, as shown in  FIGS.  8  and  9 F . However, in those embodiments in which the sub-step  241   j  of opening the EQ valve  222   a  is omitted, the sub-step  241   m  of closing the EQ valve  222   a  is also omitted. Additionally, the sub-step  241   m  may be executed to close the EQ valve  222   a  at any time before, during, or after, execution of the sub-steps  241   k  or  241   l . At the sub-step  241   n , the object is permitted passage to the well  105 B, as shown in  FIGS.  8  and  9 G . Finally, at the sub-step  241   o , the flow control device  221   a  is closed, as shown in  FIGS.  8  and  9 G . Once the sub-steps  241   a - o  are executed, the well  105 B is ready for execution of the step  245 , namely detecting or otherwise determining that a fracturing stage of the well  105 D has ended, as will be described in detail below in connection with  FIGS.  10  and  11   . 
     Referring to  FIGS.  10  and  11   , in an embodiment, various sub-steps  246   a - c  of the step  245  of the method  175  illustrated in  FIG.  1 B  are shown in detail, which step  245  is or includes detecting or otherwise determining that a fracturing stage of the well  105 D has ended. At the sub-step  246   a , the n 1  well (e.g., well  105 D) is monitored for an external signal indicating the fracturing stage has ended, as shown in  FIG.  10   . At the sub-step  246   b , the n 1  well&#39;s frac data is monitored to determine whether the fracturing stage has ended, as shown in  FIG.  10   . Finally, at the sub-step  246   c , the zipper valves  170   a - b  associated with the n 1 +1 well (e.g., well  105 B) are dequeued and compared against the frac order (if available). During execution of the sub-steps  246   a - c : grease from the grease system  155  is communicated to the corresponding GPs  200   a - b  of the zipper valves  170   a - b , respectively, as shown in  FIG.  11    (indicated by arrows  232   k  in  FIG.  5 B ); and hydraulic fracturing fluid is communicated from the zipper manifold  145  to the well  105 D, as shown in  FIG.  11    (indicated by arrows  232   l  and  232   m  in  FIG.  11   ). 
     Referring to  FIG.  12   , in an embodiment, various sub-steps  251   a - c  of the step  250  of the method  175  illustrated in  FIG.  1 B  are shown in detail, which step  250  is or includes determining whether to permit a regular swap or a CP swap from hydraulically fracturing (at a step  262 ) the well  105 D to hydraulically fracturing (at the step  262 ) the well  105 B, by, for example: checking an idle rate of the hydraulic fracturing system  100  at the sub-step  251   a ; and detecting or otherwise determining that an idle rate of the hydraulic fracturing system  100  is below an upper threshold and above a lower threshold at the sub-step  251   b , or, at the sub-step  251   c , detecting or otherwise determining that the idle rate of the hydraulic fracturing system  100  is below the lower threshold. More particularly, as shown in  FIG.  12   : at the sub-step  251   a , a frac rate of the n 1  well (e.g., well  105 D) is checked; and, at the sub-step  251   b , if the frac rate of the n 1  well is below the upper threshold rate (e.g., 10 bbl) and above the lower threshold rate (e.g., 0 bbl) for a threshold amount of time (e.g.,  10   s ), a CP swap from hydraulically fracturing the n 1  well to hydraulically fracturing the n 1 +1 well is permitted at step  260 , but, at the sub-step  251   c , if the frac rate of the n 1  well is below the lower threshold rate for a threshold amount of time, only a regular swap from hydraulically fracturing the n 1  well to hydraulically fracturing the n 1 +1 well is permitted at step  255 . 
     Referring to  FIGS.  13  and  14 A through  14 B , in an embodiment, various sub-steps  256   a - c  of the step  255  of the method  175  illustrated in  FIG.  1 B  are shown in detail, which step  255  is or includes executing the regular swap from hydraulically fracturing (at the step  262 ) the n 1  well (e.g., well  105 D) to hydraulically fracturing (at the step  262 ) the n 1 +1 well (e.g., well  105 B). At the sub-step  256   a , the n 1  well&#39;s (e.g., well  105 D) zipper valves  170   a - b  are closed, and grease from the grease system  155  is withheld from the corresponding GPs  200   a - b , as shown in  FIGS.  13  and  14 A . At the sub-step  256   b , a signal to advance is received, as shown in  FIG.  13   . For example, a user input such as a screen click may be received at the sub-step  256   b . In addition, or instead, an external signal, such as an external signal from the frac operator, may be received at the sub-step  256   b . In addition, or instead, a signal to advance may be generated by detecting or otherwise determining that pressure equalization has been achieved to within a threshold amount between the hydraulic fracturing pressure in the zipper manifold  145  and the fluid pressure in the n 1 +1 well (e.g., well  105 B) for a threshold amount of time. At the sub-step  256   c , the n 1 +1 well&#39;s zipper valves  170   a - b  are opened, as shown in  FIGS.  13  and  14 B , so that hydraulic fracturing fluid is communicated from the zipper manifold  145  to the n 1 +1 well (indicated by arrows  232   n  and  232   o  in  FIGS.  14 B ), and grease from the grease system  155  is communicated to the corresponding GPs  200   a - b  (indicated by arrow  232   p  in  FIG.  14 B ). 
     Referring to  FIGS.  15  and  16 A through  16 E , in an embodiment, various sub-steps  261   a - c  of the step  260  of the method  175  illustrated in  FIG.  1 B  are shown in detail, which step  260  is or includes executing the CP swap from hydraulically fracturing (at the step  262 ) the n 1  well (e.g., well  105 D) to hydraulically fracturing (at the step  262 ) the n 1 +1 well (e.g., well  105 B). At the sub-step  261   a , the n 1 +1 well&#39;s (e.g., well  105 B) zipper valves  170   a - b  are opened, as shown in  FIGS.  15  and  16 A , hydraulic fracturing fluid is communicated from the zipper manifold  145  to the n 1 +1 well (indicated by arrows  232   n  and  232   o  in  FIG.  16 A ), and grease from the grease system  155  is communicated to the corresponding GPs  200   a - b  (indicated by arrow  232   p  in  FIG.  16 A ). At the sub-step  261   b , both the n 1 +1 well&#39;s (e.g., well  105 B) zipper valves  170   a - b  and the n 1  well&#39;s (e.g., well D) zipper valves  170   a - b  are allowed to fully open, as shown in  FIGS.  15 ,  16 A and  16 B , so that: hydraulic fracturing fluid is communicated from the zipper manifold  145  to the n 1  well (indicated by arrows  232   l  and  232   m  in  FIG.  16 B ) and the n 1 +1 well (indicated by arrows  232   n  and  232   o  in  FIG.  14 A ); and grease from the grease system  155  is communicated to the corresponding GPs  200   a - b  (indicated by arrows  232   p  and  232   k  in  FIGS.  16 A and  16 B , respectively). Finally, at the sub-step  261   c , the n 1  well&#39;s (e.g., well  105 D) zipper valves  170   a - b  are closed, as shown in  FIGS.  15  and  16 C , and grease from the grease system  155  is withheld from the corresponding GPs  200   a - b.    
     As shown in  FIGS.  16 D and  16 E , executing the CP swap from hydraulically fracturing (at the step  262 ) the n 1  well (e.g., well  105 D) to hydraulically fracturing (at the step  262 ) the n 1 +1 well (e.g., well  105 B) transitions the zipper valves from one well to the other, opening the second well and subsequently shutting-in the first well, all while pumping. The transition is instantaneous and the total time between stages measured at treatment pressure is less than 20 seconds (as fast as 19 seconds in some instances). 
     Referring to  FIGS.  17  and  18 A through  18 G , in an embodiment, various sub-steps  266   a - s  of the step  265  of the method  175  illustrated in  FIG.  1 B  are shown in detail, which step  265  is or includes latching, filling, and pressure testing the frac leg  150 E associated with the well  105 E in preparation for perforating a stage of the well  105 E using the wireline perforating system  177  (in a manner similar to that described above in connection with the well  105 A and shown in  FIGS.  5 A through  5 C ). At the sub-step  266   a , the lubricator  220  is stabbed into the latch  234 , as shown in  FIGS.  17  and  18 A  (indicated by arrow  232   q  in  FIG.  18 A ). At the sub-step  266   b , the EQ valve  222   c  is closed, as shown in  FIGS.  17  and  18 B . At the sub-step  266   c , the latch close relay is energized to close the latch  234 , thereby connecting the lubricator  220  to the valve apparatus  210 , as shown in  FIGS.  17  and  18 C . At the sub-step  266   d , a latch close proximity switch is checked to determine whether the latch  234  has successfully latched the lubricator  220  to the valve apparatus  210 . At the sub-step  266   e , once it is determined that the latch  234  has successfully latched the lubricator  220  to the valve apparatus  210 , the latch close relay is de-energized, as shown in  FIG.  17   . At the sub-step  266   f , a test pressure relay is energized, as shown in  FIG.  17   . At the sub-step  266   g , a determination is made as to whether the connection of the lubricator  220  to the valve apparatus  210  via the latch  234  is or is not capable of holding pressure, as shown in  FIG.  17   . At the sub-step  266   h , once the determination is made that the connection of the lubricator  220  to the valve apparatus  210  via the latch  234  is capable of holding pressure, the test pressure relay is de-energized, as shown in  FIG.  17   . 
     At the sub-step  266   i , the drain  223  is opened, as shown in  FIGS.  17  and  18 D . At the sub-step  266   j , the EQ valve  222   c  is opened, as shown in  FIGS.  17  and  18 E . At the sub-step  266   k , the auto-fill pump of the pump station  224   a  is turned on to fill the lubricator  220  via the open drain  223 , as shown in  FIGS.  17  and  18 E  (indicated by arrow  232   r  in  FIG.  18 E ). At the sub-step  266   l , the auto-fill pump is allowed to finish auto-filling the lubricator  220 , as shown in  FIG.  17   . At the sub-step  266   m , the drain  223  is closed, as shown in  FIGS.  17  and  18 F . At the sub-step  266   n , the EQ valve  222   c  is closed, as shown in  FIGS.  17  and  18 F . At the sub-step  266   o , the EQ valve  222   b  is opened, as shown in  FIGS.  17  and  18 F . At the sub-step  266   p , the boost pump(s)  224   b  is/are turned on to increase the fluid pressure within the lubricator  220 , as shown in  FIGS.  17  and  18 F  (indicated by arrow  232   s  in  FIG.  18 F ). At the sub-step  266   q , a determination is made as to whether the pressure in the lubricator  220  comes to within the pressure in the well  105 E by a threshold amount (e.g., 500 PSI), as shown in  FIG.  17   . Once the determination is made that the pressure in the lubricator  220  comes to within the pressure in the well  105 E by the threshold amount, the boost pump(s)  224   b  is/are turned off at the sub-step  266   r , and the EQ valve  222   b  is closed at the sub-step  266   s  in preparation for the next wireline swap (e.g., to the well  105 E), as shown in  FIGS.  17  and  18 G . 
     Referring to  FIGS.  19 A and  19 B , in an embodiment, a method  270  for fracturing the wells  105 A through  105 C+n using the hydraulic fracturing system  100  of  FIG.  1 A  is illustrated, which method  270  includes swapping from simultaneously fracturing the wells n 1  and n 3  (e.g., wells  105 D and  105 X) to simultaneously fracturing the wells n 1 +1 and n 3 +1 (e.g., wells  105 B and  105 V). More particularly, the method  270  includes steps substantially identical to corresponding steps of the method  175  described above, which steps are given the same reference numerals. In addition, the method  270  includes additional steps executable to simultaneously fracture the n 1  and n 3  wells (e.g., wells  105 D and  105 X), and to swap from simultaneously fracturing the n 1  and n 3  wells to simultaneously fracturing the n 1 +1 and n 3 +1 wells (e.g., wells  105 B and  105 V), which additional steps are given the same reference numerals, except that the suffix “′” is added. Specifically, in some instances the suffix “′” signifies that the referenced step of the method  270  is substantially identical to the corresponding step of the method  175 , except that the referenced step is instead performed on a different one of the wells than that on which the corresponding step of the method  175  is performed (i.e., the steps  225 ′,  230 ′,  235 ′,  238   a ′,  239 ′,  238   b ′,  263   a ′,  264 ′,  263   b ′,  265 ′, and  268 ′ fall into this category), while, in other instances, the suffix “′” signifies that the referenced step of the method  270  is substantially similar to the corresponding step of the method  175 , except that the referenced step is simultaneously performed on another one of the wells other than that on which the corresponding step of the method  175  is performed (i.e., the steps  240 ′,  245 ′,  250 ′,  255 ′,  260 ′, and  262 ′ fall into this category). In one or more embodiments, the controller  156  is adapted to control the grease system  155 , the frac legs  150 A through  150 C+n, or both, in order to execute the method  270  described herein. 
     Referring to  FIG.  20   , with continuing reference to  FIGS.  1 A through  19 B , an illustrative node  1000  for implementing one or more of the embodiments of one or more of the controller(s) (e.g., the controller  156 ), element(s), apparatus, system(s) (e.g., the hydraulic fracturing system  100 ), method(s) (e.g., the method  175 , the method  270 , or both), step(s), and/or sub-step(s), or any combination thereof, described above and/or illustrated in  FIGS.  1 A through  19 B  is depicted. The node  1000  includes a microprocessor  1000   a , an input device  1000   b , a storage device  1000   c , a video controller  1000   d , a system memory  1000   e , a display  1000   f , and a communication device  1000   g  all interconnected by one or more buses  1000   h . In one or more embodiments, the storage device  1000   c  may include a hard drive, CD-ROM, optical drive, any other form of storage device and/or any combination thereof. In one or more embodiments, the storage device  1000   c  may include, and/or be capable of receiving, a CD-ROM, DVD-ROM, or any other form of non-transitory computer-readable medium that may contain executable instructions. In one or more embodiments, the communication device  1000   g  may include a modem, network card, or any other device to enable the node  1000  to communicate with other node(s). In one or more embodiments, the node and the other node(s) represent a plurality of interconnected (whether by intranet or Internet) computer systems, including without limitation, personal computers, mainframes, PDAs, smartphones and cell phones. 
     In one or more embodiments, one or more of the embodiments described above and/or illustrated in  FIGS.  1 A through  19 B  include at least the node  1000  and/or components thereof, and/or one or more nodes that are substantially similar to the node  1000  and/or components thereof. In one or more embodiments, one or more of the above-described components of the node  1000  and/or the embodiments described above and/or illustrated in  FIGS.  1 A through  19 B  include respective pluralities of same components. 
     In one or more embodiments, one or more of the embodiments described above and/or illustrated in  FIGS.  1 A through  19 B  include a computer program that includes a plurality of instructions, data, and/or any combination thereof; an application written in, for example, Arena, HyperText Markup Language (HTML), Cascading Style Sheets (CSS), JavaScript, Extensible Markup Language (XML), asynchronous JavaScript and XML (Ajax), and/or any combination thereof; a web-based application written in, for example, Java or Adobe Flex, which in one or more embodiments pulls real-time information from one or more servers, automatically refreshing with latest information at a predetermined time increment; or any combination thereof. 
     In one or more embodiments, a computer system typically includes at least hardware capable of executing machine readable instructions, as well as the software for executing acts (typically machine-readable instructions) that produce a desired result. In one or more embodiments, a computer system may include hybrids of hardware and software, as well as computer sub-systems. 
     In one or more embodiments, hardware generally includes at least processor-capable platforms, such as client-machines (also known as personal computers or servers), and hand-held processing devices (such as smart phones, tablet computers, or personal computing devices (PCDs), for example). In one or more embodiments, hardware may include any physical device that is capable of storing machine-readable instructions, such as memory or other data storage devices. In one or more embodiments, other forms of hardware include hardware sub-systems, including transfer devices such as modems, modem cards, ports, and port cards, for example. 
     In one or more embodiments, software includes any machine code stored in any memory medium, such as RAM or ROM, and machine code stored on other devices (such as floppy disks, flash memory, or a CD-ROM, for example). In one or more embodiments, software may include source or object code. In one or more embodiments, software encompasses any set of instructions capable of being executed on a node such as, for example, on a client machine or server. 
     In one or more embodiments, combinations of software and hardware could also be used for providing enhanced functionality and performance for certain embodiments of the present disclosure. In an embodiment, software functions may be directly manufactured into a silicon chip. Accordingly, it should be understood that combinations of hardware and software are also included within the definition of a computer system and are thus envisioned by the present disclosure as possible equivalent structures and equivalent methods. 
     In one or more embodiments, computer readable mediums include, for example, passive data storage, such as a random-access memory (RAM) as well as semi-permanent data storage such as a compact disk read only memory (CD-ROM). One or more embodiments of the present disclosure may be embodied in the RAM of a computer to transform a standard computer into a new specific computing machine. In one or more embodiments, data structures are defined organizations of data that may enable an embodiment of the present disclosure. In an embodiment, a data structure may provide an organization of data, or an organization of executable code. 
     In one or more embodiments, any networks and/or one or more portions thereof may be designed to work on any specific architecture. In an embodiment, one or more portions of any networks may be executed on a single computer, local area networks, client-server networks, wide area networks, internets, hand-held and other portable and wireless devices and networks. 
     In one or more embodiments, a database may be any standard or proprietary database software. In one or more embodiments, the database may have fields, records, data, and other database elements that may be associated through database specific software. In one or more embodiments, data may be mapped. In one or more embodiments, mapping is the process of associating one data entry with another data entry. In an embodiment, the data contained in the location of a character file can be mapped to a field in a second table. In one or more embodiments, the physical location of the database is not limiting, and the database may be distributed. In an embodiment, the database may exist remotely from the server, and run on a separate platform. In an embodiment, the database may be accessible across the Internet. In one or more embodiments, more than one database may be implemented. 
     In one or more embodiments, a plurality of instructions stored on a computer readable medium may be executed by one or more processors to cause the one or more processors to carry out or implement in whole or in part one or more of the embodiments of one or more of the controller(s) (e.g., the controller  156 ), element(s), apparatus, system(s) (e.g., the hydraulic fracturing system  100 ), method(s) (e.g., the method  175 , the method  270 , or both), step(s), and/or sub-step(s), or any combination thereof, described above and/or illustrated in  FIGS.  1 A through  19 B . In one or more embodiments, such a processor may include one or more of the microprocessor  1000   a , any processor(s) that are part of the components of the hydraulic fracturing system  100 , such as, for example, the controller  156 , and/or any combination thereof, and such a computer readable medium may be distributed among one or more components of the system. In one or more embodiments, such a processor may execute the plurality of instructions in connection with a virtual computer system. In one or more embodiments, such a plurality of instructions may communicate directly with the one or more processors, and/or ay interact with one or more operating systems, middleware, firmware, other applications, and/or any combination thereof, to cause the one or more processors to execute the instructions. 
     A first method has been disclosed. The first method generally includes: (a) permitting performance of a first hydraulic fracturing operation on a first well, which first hydraulic fracturing operation includes pumping fluid into the first well via a first valve associated with the first well, and measuring a flow rate of the fluid being pumped into the first well; (b) determining that the flow rate of the fluid being pumped into the first well is below a flow rate threshold and has been below the flow rate threshold for a threshold amount of time; (c) during pumping of the fluid into the first well via the first valve, opening a second valve associated with a second well; (d) permitting performance of a second hydraulic fracturing operation on the second well, which second hydraulic fracturing operation includes pumping fluid into the second well via the second valve; and (e) during pumping of the fluid into the second well via the second valve, closing the first valve associated with the first well; wherein, during each of steps (a), (b), (c), (d), and (e), fluid is continuously pumped to the first valve, the second valve, or both the first valve and the second valve. In one or more embodiments, each of the first and second valves is in fluid communication with a hydraulic manifold from which fluid is pumped to the first valve and/or the second valve; and, during each of steps (a), (b), (c), (d), and (e), fluid is continuously pumped from the hydraulic manifold to the first valve, the second valve, or both the first valve and the second valve. In one or more embodiments, the second valve is opened after step (b). In one or more embodiments, the first valve includes a grease port; and the method further includes withholding grease from the grease port after step (e). In one or more embodiments, the second valve includes a grease port; and the method further includes: during and/or after opening the second valve, communicating grease to the grease port of the second valve. In one or more embodiments, each of the first and second valves is a zipper valve. In one or more embodiments, step (d): further includes measuring a flow rate of the fluid being pumped into the second well; and is, or is part of, a hydraulic fracturing stage of the second well; and the method further includes: determining that the hydraulic fracturing stage of the second well has ended; determining that the flow rate of the fluid being pumped into the second well is above the flow rate threshold; closing the second valve associated with the second well; withholding grease from a grease port of the second valve; receiving a signal to advance; opening a third valve associated with a third well; and during and/or after opening the third valve, communicating grease to a grease port of the third valve. 
     A first apparatus has also been disclosed. The first apparatus generally includes: a non-transitory computer readable medium; and a plurality of instructions stored on the non-transitory computer readable medium and executable by one or more processors, wherein, when the instructions are executed by the one or more processors, the following steps are executed: (a) permitting performance of a first hydraulic fracturing operation on a first well, which first hydraulic fracturing operation includes pumping fluid into the first well via a first valve associated with the first well, and measuring a flow rate of the fluid being pumped into the first well; (b) determining that the flow rate of the fluid being pumped into the first well is below a flow rate threshold and has been below the flow rate threshold for a threshold amount of time; (c) during pumping of the fluid into the first well via the first valve, opening a second valve associated with a second well; (d) permitting performance of a second hydraulic fracturing operation on the second well, which second hydraulic fracturing operation includes pumping fluid into the second well via the second valve; and (e) during pumping of the fluid into the second well via the second valve, closing the first valve associated with the first well; wherein, during each of steps (a), (b), (c), (d), and (e), fluid is continuously pumped to the first valve, the second valve, or both the first valve and the second valve. In one or more embodiments, each of the first and second valves is in fluid communication with a hydraulic manifold from which fluid is pumped to the first valve and/or the second valve; wherein, during each of steps (a), (b), (c), (d), and (e), fluid is continuously pumped from the hydraulic manifold to the first valve, the second valve, or both the first valve and the second valve. In one or more embodiments, the second valve is opened after step (b). In one or more embodiments, the first valve includes a grease port; and, when the instructions are executed by the one or more processors, the following step is also executed: withholding grease from the grease port after step (e). In one or more embodiments, the second valve includes a grease port; and, when the instructions are executed by the one or more processors, the following step is also executed: during and/or after opening the second valve, communicating grease to the grease port of the second valve. In one or more embodiments, each of the first and second valves is a zipper valve. In one or more embodiments, step (d): further includes measuring a flow rate of the fluid being pumped into the second well; and is, or is part of, a hydraulic fracturing stage of the second well; and, when the instructions are executed by the one or more processors, the following steps are also executed: determining that the hydraulic fracturing stage of the second well has ended; determining that the flow rate of the fluid being pumped into the second well is above the flow rate threshold; closing the second valve associated with the second well; withholding grease from a grease port of the second valve; receiving a signal to advance; opening a third valve associated with a third well; and during and/or after opening the third valve, communicating grease to a grease port of the third valve. 
     A second method has also been disclosed. The second method generally includes: (a) queuing, using a controller, a first well in a first hydraulic fracturing queue, which first hydraulic fracturing queue is associated with a first plurality of wells standing by for hydraulic fracturing, including at least the first well and a second well; (b) dequeuing, using the controller, the second well from the first hydraulic fracturing queue; (c) permitting hydraulic fracturing of the second well; (d) dequeuing, using the controller, the first well from the first hydraulic fracturing queue; and (e) swapping from permitting hydraulic fracturing of the second well to permitting hydraulic fracturing of the first well. In one or more embodiments, step (c) includes opening a second valve associated with the second well to permit pumping of fluid into the second well via the second valve; and step (e) includes: opening a first valve associated with the first well to permit pumping of fluid into the first well via the first valve; and closing the second valve associated with the second well. In one or more embodiments, step (c) further includes measuring a flow rate of the fluid being pumped into the second well. In one or more embodiments, step (e) further includes, in response to determining that the flow rate of the fluid being pumped into the second well is below a flow rate threshold and has been below the flow rate threshold for a threshold amount of time, the first valve associated with the first well is opened at step (e) before the second valve associated with the second well is closed at step (e). In one or more embodiments, the step (e) further includes, in response to determining that the flow rate of the fluid being pumped into the second well is above a flow rate threshold, the first valve associated with the first well is opened at step (e) after the second valve associated with the second well is closed at step (e). In one or more embodiments, the method further includes: (f) queuing, using the controller, a third well in a second hydraulic fracturing queue, which second hydraulic fracturing queue is associated with a second plurality of wells standing by for hydraulic fracturing, including at least the third well and a fourth well; (g) dequeuing, using the controller, the fourth well from the second hydraulic fracturing queue; (h) permitting hydraulic fracturing of the fourth well; (i) dequeuing, using the controller, the third well from the second hydraulic fracturing queue; and (j) swapping from permitting hydraulic fracturing of the fourth well to permitting hydraulic fracturing of the third well. In one or more embodiments, steps (c) and (h) are executed simultaneously using hydraulic fracturing fluid from a hydraulic manifold; and steps (e) and (j) are executed simultaneously using hydraulic fracturing fluid from the hydraulic manifold. In one or more embodiments, step (c) includes opening a second valve associated with the second well to permit pumping of fluid into the second well via the second valve; step (e) includes: opening a first valve associated with the first well to permit pumping of fluid into the first well via the first valve; and closing the second valve associated with the second well; step (h) includes opening a fourth valve associated with the fourth well to permit pumping of fluid into the fourth well via the fourth valve; and step (j) includes: opening a third valve associated with the third well to permit pumping of fluid into the third well via the third valve; and closing the fourth valve associated with the fourth well. 
     A second apparatus has also been disclosed. The second apparatus generally includes: a non-transitory computer readable medium; and a plurality of instructions stored on the non-transitory computer readable medium and executable by one or more processors, wherein, when the instructions are executed by the one or more processors, the following steps are executed: (a) queuing a first well in a first hydraulic fracturing queue, which first hydraulic fracturing queue includes a first plurality of wells standing by for hydraulic fracturing, including at least the first well and a second well; (b) dequeuing the second well from the first hydraulic fracturing queue; (c) permitting hydraulic fracturing of the second well; (d) dequeuing the first well from the first hydraulic fracturing queue; and (e) swapping from permitting hydraulic fracturing of the second well to permitting hydraulic fracturing of the first well. In one or more embodiments, step (c) includes opening a second valve associated with the second well to permit pumping of fluid into the second well via the second valve; and step (e) includes: opening a first valve associated with the first well to permit pumping of fluid into the first well via the first valve; and closing the second valve associated with the second well. In one or more embodiments, step (c) further includes measuring a flow rate of the fluid being pumped into the second well. In one or more embodiments, in response to determining that the flow rate of the fluid being pumped into the second well is below a flow rate threshold and has been below the flow rate threshold for a threshold amount of time, the first valve associated with the first well is opened at step (e) before the second valve associated with the second well is closed at step (e). In one or more embodiments, in response to determining that the flow rate of the fluid being pumped into the second well is above a flow rate threshold, the first valve associated with the first well is opened at step (e) after the second valve associated with the second well is closed at step (e). In one or more embodiments, when the instructions are executed by the one or more processors, the following steps are also executed: (f) queuing a third well in a second hydraulic fracturing queue, which second hydraulic fracturing queue includes a second plurality of wells standing by for hydraulic fracturing, including at least the third well and a fourth well; (g) dequeuing the fourth well from the second hydraulic fracturing queue; (h) permitting hydraulic fracturing of the fourth well; (i) dequeuing the third well from the second hydraulic fracturing queue; and (j) swapping from permitting hydraulic fracturing of the fourth well to permitting hydraulic fracturing of the third well. In one or more embodiments, steps (c) and (h) are executed simultaneously using hydraulic fracturing fluid from a hydraulic manifold; and steps (e) and (j) are executed simultaneously using hydraulic fracturing fluid from the hydraulic manifold. In one or more embodiments, step (c) includes opening a second valve associated with the second well to permit pumping of fluid into the second well via the second valve; step (e) includes: opening a first valve associated with the first well to permit pumping of fluid into the first well via the first valve; and closing the second valve associated with the second well; step (h) includes opening a fourth valve associated with the fourth well to permit pumping of fluid into the fourth well via the fourth valve; and step (j) includes: opening a third valve associated with the third well to permit pumping of fluid into the third well via the third valve; and closing the fourth valve associated with the fourth well. 
     It is understood that variations may be made in the foregoing without departing from the scope of the present disclosure. 
     In several embodiments, the elements and teachings of the various embodiments may be combined in whole or in part in some (or all) of the embodiments. In addition, one or more of the elements and teachings of the various embodiments may be omitted, at least in part, and/or combined, at least in part, with one or more of the other elements and teachings of the various embodiments. 
     Any spatial references, such as, for example, “upper,” “lower,” “above,” “below,” “between,” “bottom,” “vertical,” “horizontal,” “angular,” “upwards,” “downwards,” “side-to-side,” “left-to-right,” “right-to-left,” “top-to-bottom,” “bottom-to-top,” “top,” “bottom,” “bottom-up,” “top-down,” etc., are for the purpose of illustration only and do not limit the specific orientation or location of the structure described above. 
     In several embodiments, while different steps, processes, and procedures are described as appearing as distinct acts, one or more of the steps, one or more of the processes, and/or one or more of the procedures may also be performed in different orders, simultaneously and/or sequentially. In several embodiments, the steps, processes, and/or procedures may be merged into one or more steps, processes and/or procedures. 
     In several embodiments, one or more of the operational steps in each embodiment may be omitted. Moreover, in some instances, some features of the present disclosure may be employed without a corresponding use of the other features. Moreover, one or more of the above-described embodiments and/or variations may be combined in whole or in part with any one or more of the other above-described embodiments and/or variations. 
     Although several embodiments have been described in detail above, the embodiments described are illustrative only and are not limiting, and those skilled in the art will readily appreciate that many other modifications, changes and/or substitutions are possible in the embodiments without materially departing from the novel teachings and advantages of the present disclosure. Accordingly, all such modifications, changes, and/or substitutions are intended to be included within the scope of this disclosure as defined in the following claims. In the claims, any means-plus-function clauses are intended to cover the structures described herein as performing the recited function and not only structural equivalents, but also equivalent structures. Moreover, it is the express intention of the applicant not to invoke 35 U.S.C. § 112(f) for any limitations of any of the claims herein, except for those in which the claim expressly uses the word “means” together with an associated function.