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`PATENT FAMILY SPECIFICATION COMPARISONS
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`CONTENTS
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`’770 COMPARISON WITH U.S. PATENT 11,401,779 (’779) ............................... 2
`’779 COMPARISON WITH (cid:1932)663 PROVISIONAL ............................................... 22
`’779 COMPARISON WITH U.S. APP. NO. 17/319,854 (CIP-1 PARENT) ......... 41
`’779 COMPARISON WITH U.S. APP. NO. 16/855,749 (CIP-2 PARENT) ......... 86
`’779 COMPARISON WITH U.S. APP. NO. 16/248,648 (CIP-3-A PARENT) ...131
`’779 COMPARISON WITH U.S. APP. NO. 16/803,156 (CIP-3-B PARENT) ...156
`’779 COMPARISON WITH U.S. APP. NO. 16/248,633 (CIP-4-A PARENT) ...185
`’779 COMPARISON WITH U.S. APP. NO. 16/436,623 (CIP-4-B PARENT) ....208
`’779 COMPARISON WITH U.S. APP. NO. 16/100,741 (CIP-4-C PARENT) ...241
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`’770 COMPARISON WITH U.S. PATENT 11,401,779 (’779)
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`Description
`CROSS-REFERENCE TO RELATED APPLICATIONS
`This application is a continuation of U.S. patent application Ser. No. 17/388,716 (the “'716
`Application”), filed Jul. 29, 2021, which claims the benefit of the filing date of, and priority to,
`U.S. applicationPatent Application No. 63/189,663, filed May 17, 2021, the entire
`disclosuredisclosures of which isare hereby incorporated herein by reference.
`This applicationThe '716 Application is also a continuation-in-part (CIP) of U.S. patent
`application Ser. No. 17/319,854 (the “'854 applicationApplication”), filed May 13, 2021, the
`entire disclosure of which is hereby incorporated herein by reference.
`The '854 applicationApplication is a continuation-in-part (CIP) of U.S. patent application Ser.
`No. 16/855,749 (the “'749 applicationApplication”), filed Apr. 22, 2020, the entire disclosure of
`which is hereby incorporated herein by reference. The '749 applicationApplication 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 '749 applicationApplication is a continuation-in-part (CIP) of U.S. patent application Ser.
`No. 16/248,648 (the “'648 applicationApplication”), 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
`'648 applicationApplication 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 '749 applicationApplication is also a CIP of U.S. patent application Ser. No. 16/803,156 (the
`“'156 applicationApplication”), filed Feb. 27, 2020, the entire disclosure of which is hereby
`incorporated herein by reference. The '156 applicationApplication is a CIP of U.S. patent
`application Ser. No. 16/248,633 (the “'633 applicationApplication”), 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 '633 applicationApplication claims the benefit of the filing date of, and priority
`to, U.S. Patent Application No. 62/617,438 (the “'438 applicationApplication”), filed Jan. 15,
`2018, the entire disclosure of which is hereby incorporated herein by reference.
`The '156 applicationApplication is also a CIP of U.S. patent application Ser. No. 16/436,623 (the
`“'623 applicationApplication”), filed Jun. 10, 2019, the entire disclosure of which is hereby
`incorporated herein by reference. The '623 applicationApplication 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 '156 applicationApplication is also a CIP of U.S. patent application Ser. No. 16/100,741 (the
`“'741 applicationApplication”), 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 '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 '749 applicationApplication 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.
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`This applicationThe '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. 1A 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. 1B 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. 1A,
`according to one or more embodiments.
`FIG. 2A schematically illustrates execution of one or more sub-step(s) of a first step of the
`method illustrated in FIG. 1B, 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. 2B schematically illustrates execution of one or more additional sub-step(s) of the first step
`of the method illustrated in FIG. 1B, according to one or more embodiments.
`FIG. 2C schematically illustrates execution of one or more additional sub-step(s) of the first step
`of the method illustrated in FIG. 1B, according to one or more embodiments.
`FIG. 2D schematically illustrates execution of one or more additional sub-step(s) of the first step
`of the method illustrated in FIG. 1B, according to one or more embodiments.
`FIG. 2E schematically illustrates execution of one or more additional sub-step(s) of the first step
`of the method illustrated in FIG. 1B, according to one or more embodiments.
`FIG. 2F schematically illustrates execution of one or more additional sub-step(s) of the first step
`of the method illustrated in FIG. 1B, according to one or more embodiments.
`FIG. 2G schematically illustrates execution of one or more additional sub-step(s) of the first step
`of the method illustrated in FIG. 1B, according to one or more embodiments.
`FIG. 3 is a flow diagram illustrating the various sub-steps, illustrated schematically in FIGS. 2A
`and 2G, of the first step of the method illustrated in FIG. 1B, 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. 1B, 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. 5A schematically illustrates execution of one or more sub-step(s) of the second step of the
`method illustrated in FIG. 1B, according to one or more embodiments.
`FIG. 5B schematically illustrates execution of one or more additional sub-step(s) of the second
`step of the method illustrated in FIG. 1B, according to one or more embodiments.
`FIG. 5C schematically illustrates execution of one or more additional sub-step(s) of the second
`step of the method illustrated in FIG. 1B, 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. 1B, 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. 7A schematically illustrates execution of one or more sub-step(s) of the third step of the
`method illustrated in FIG. 1B, according to one or more embodiments.
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`FIG. 7B schematically illustrates execution of one or more additional sub-step(s) of the third
`step of the method illustrated in FIG. 1B, according to one or more embodiments.
`FIG. 7C schematically illustrates execution of one or more additional sub-step(s) of the third
`step of the method illustrated in FIG. 1B, according to one or more embodiments.
`FIG. 7D schematically illustrates execution of one or more additional sub-step(s) of the third
`step of the method illustrated in FIG. 1B, according to one or more embodiments.
`FIG. 7E schematically illustrates execution of one or more additional sub-step(s) of the third
`step of the method illustrated in FIG. 1B, according to one or more embodiments.
`FIG. 7F schematically illustrates execution of one or more additional sub-step(s) of the third
`step of the method illustrated in FIG. 1B, according to one or more embodiments.
`FIG. 7G schematically illustrates execution of one or more additional sub-step(s) of the third
`step of the method illustrated in FIG. 1B, according to one or more embodiments.
`FIG. 7H schematically illustrates execution of one or more additional sub-step(s) of the third
`step of the method illustrated in FIG. 1B, according to one or more embodiments.
`FIG. 7I schematically illustrates execution of one or more additional sub-step(s) of the third step
`of the method illustrated in FIG. 1B, 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. 1B, 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. 9A schematically illustrates execution of one or more sub-step(s) of the fourth step of the
`method illustrated in FIG. 1B, according to one or more embodiments.
`FIG. 9B schematically illustrates execution of one or more additional sub-step(s) of the fourth
`step of the method illustrated in FIG. 1B, according to one or more embodiments.
`FIG. 9C schematically illustrates execution of one or more additional sub-step(s) of the fourth
`step of the method illustrated in FIG. 1B, according to one or more embodiments.
`FIG. 9D schematically illustrates execution of one or more additional sub-step(s) of the fourth
`step of the method illustrated in FIG. 1B, according to one or more embodiments.
`FIG. 9E schematically illustrates execution of one or more additional sub-step(s) of the fourth
`step of the method illustrated in FIG. 1B, according to one or more embodiments.
`FIG. 9F schematically illustrates execution of one or more additional sub-step(s) of the fourth
`step of the method illustrated in FIG. 1B, according to one or more embodiments.
`FIG. 9G schematically illustrates execution of one or more additional sub-step(s) of the fourth
`step of the method illustrated in FIG. 1B, 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. 1B, 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. 1B, 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. 1B, 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. 1B, 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.
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`FIG. 14A schematically illustrates execution of one or more sub-step(s) of the seventh step of
`the method illustrated in FIG. 1B, according to one or more embodiments.
`FIG. 14B schematically illustrates execution of one or more additional sub-step(s) of the seventh
`step of the method illustrated in FIG. 1B, 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. 1B, 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. 16A schematically illustrates execution of one or more sub-step(s) of the eighth step of the
`method illustrated in FIG. 1B, according to one or more embodiments.
`FIG. 16B schematically illustrates execution of one or more additional sub-step(s) of the eighth
`step of the method illustrated in FIG. 1B, according to one or more embodiments.
`FIG. 16C schematically illustrates execution of one or more additional sub-step(s) of the eighth
`step of the method illustrated in FIG. 1B, according to one or more embodiments.
`FIG. 16D is a chart illustrating execution of one or more of the various sub-steps, schematically
`illustrated in FIGS. 16A through 16C, of the eighth step of the method illustrated in FIG. 1B,
`according to one or more embodiments.
`FIG. 16E is another chart illustrating execution of one or more of the various sub-steps,
`schematically illustrated in FIGS. 16A through 16C, of the eighth step of the method illustrated
`in FIG. 1B, 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. 1B, 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. 18A schematically illustrates execution of one or more sub-step(s) of the ninth step of the
`method illustrated in FIG. 1B, according to one or more embodiments.
`FIG. 18B schematically illustrates execution of one or more additional sub-step(s) of the ninth
`step of the method illustrated in FIG. 1B, according to one or more embodiments.
`FIG. 18C schematically illustrates execution of one or more additional sub-step(s) of the ninth
`step of the method illustrated in FIG. 1B, according to one or more embodiments.
`FIG. 18D schematically illustrates execution of one or more additional sub-step(s) of the ninth
`step of the method illustrated in FIG. 1B, according to one or more embodiments.
`FIG. 18E schematically illustrates execution of one or more additional sub-step(s) of the ninth
`step of the method illustrated in FIG. 1B, according to one or more embodiments.
`FIG. 18F schematically illustrates execution of one or more additional sub-step(s) of the ninth
`step of the method illustrated in FIG. 1B, according to one or more embodiments.
`FIG. 18G schematically illustrates execution of one or more additional sub-step(s) of the ninth
`step of the method illustrated in FIG. 1B, according to one or more embodiments.
`FIG. 19A is a flow diagram illustrating a portion of another method for fracturing wells using
`the fracturing system of FIG. 1A, 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. 19B is a flow diagram illustrating another portion of the another method of FIG. 20A,
`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.
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`DETAILED DESCRIPTION
`Referring to FIG. 1A, in an embodiment, a hydraulic fracturing system 100 for executing a
`hydraulic fracturing plan to hydraulically fracture wells 105A through 105C+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”) 150A
`through 150C+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 105A through 105C+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 150A through 150C+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 150A
`through 150C+n (which components are shown in FIGS. 2A-G, 5A-C, 7A-I, 9A-G, 11, 14A-
`B, 16A-C, and 18A-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, 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, now published as U.S. Patent Application
`Publication No. 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 '749
`applicationApplication, filed Apr. 22, 2020, 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 '854
`applicationApplication, filed May 13, 2021, 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 150A through 150C+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.
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`Referring to FIG. 1B, in an embodiment, a method 175 for hydraulically fracturing
`the wells 105A through 105C+n by executing a hydraulic fracturing plan using the hydraulic
`fracturing system 100 of FIG. 1A 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 150A associated with the well 105A, and opening the
`well 105A; at a step 230, perforating a stage of the well 105A using the wireline perforating
`system 177; at a step 235, closing the well 105A using the valve apparatus 210 and draining the
`lubricator 220; at a step 238 a, queuing the well 105A (as indicated at queue position n2) in a
`frac queue 239 in preparation for a hydraulic fracturing operation; at a step 238 b, dequeuing the
`well 105B (as indicated at queue position n1+1) from the frac queue 239 in preparation for the
`hydraulic fracturing operation; at a step 240, isolating a stage of the well 105B in preparation for
`the hydraulic fracturing operation; at a step 245, detecting or otherwise determining that a
`fracturing stage of the well 105D 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 105D to
`hydraulically fracturing (at the step 262) the well 105B; at a step 255, executing the regular swap
`from hydraulically fracturing (at the step 262) the well 105D to hydraulically fracturing (at the
`step 262) the well 105B, or, at a step 260, executing the CP swap from hydraulically fracturing
`(at the step 262) the well 105D to hydraulically fracturing (at the step 262) the well 105B; at the
`step 262, hydraulically fracturing the well 105B; optionally, at a step 263 a, queuing the
`well 105D (as indicated at queue position n1) in a wireline queue 264 in preparation for
`perforating a next stage of the well 105D; optionally, at a step 238 b, dequeuing the well 105E
`(as indicated at queue position 1) from the wireline queue 264 in preparation for perforating a
`next stage of the well 105E; and, at a step 265, latching, filling, and pressure testing the frac
`leg 150E associated with the well 105E.
`In one or more embodiments, the controller 156 is adapted to control the grease system 155,
`the frac legs 150A through 150C+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 105A through 105C+n, as shown in FIG. 1B. 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 105A through 105C+n, as shown
`in FIG. 1B. 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. 2A through 2G, in an embodiment, the frac leg 150A associated with
`the well 105A is illustrated, which frac leg 150A 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
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`communication with, the well 105A, 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 105A, 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 105A, 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 150A through 150C+n include(s), or is/are part of,
`the zipper manifold 145. In one or more embodiments, as in FIGS. 2A through 2G, the frac
`leg 150A associated with the well 105A 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 150A associated with the well 105A 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 105A. The valve apparatus 210 includes:
`a containment area 215 a (labeled “WELL”) adapted to be in fluid communication with
`the well 105A 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
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`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, 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, 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, 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 150B through 150C+n associated with each of
`the wells 105B through 105C+n, respectively, are substantially identical to the frac leg 150A
`associated with the well 105A; therefore, the frac legs 150B through 150C+n associated with
`each of the wells 105B through 105C+n will not be described in further detail. Accordingly, each
`of the frac legs 150B through 150C+n associated with the wells 105B through 105C+n includes
`features/components substantially identical to corresponding features/components of the frac
`leg 150A associated with the well 105A, 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. 2A through 2G, in an embodiment,
`various sub-steps 226 a-h of the step 225 of the method 175 illustrated in FIG. 1B are shown in
`detail, which step 225 is or includes equalizing the lubricator 220 of the frac leg 150A associated
`with the well 105A, and opening the well 105A. In one or more embodiments,
`the lubricator 220 is or includes one or more components shown and described in the '749
`applicationApplication. In addition, or instead, in one or more embodiments, the lubricator 220 is
`or includes one or more components shown and described in the '854 applicationApplication.
`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 150A, thereby aiding in pressure equalization between
`said lubricator 220 and the well 105A, as shown in FIGS. 2A and 3 (indicated
`by arrow 232 a in FIG. 2A). As shown in FIG. 1B, the step 265 of latching, filling, and pressure
`testing the frac leg 150A associated with the well 105A is executed on the frac leg 150A just
`prior to the execution of the sub-step 226 a on the f