Cross-Reference to Related Applications

[0001] This application claims the benefit of the filing date of, and priority to, U.S. Patent Application No. 62/836,761 , filed April 22, 2019, the entire disclosure of which is hereby incorporated herein by reference.

[0002] This application also claims the benefit of the filing date of, and priority to, U.S. Patent Application No. 16/803, 156 (“the Ί 56 Application”), filed February 27, 2020, the entire disclosure of which is hereby incorporated herein by reference. The Ί 56 Application is a CIP of U.S. Patent Application No. 16/248,633 (the“’633 Application”), filed January 15, 2019, the entire disclosure of which is hereby incorporated herein by reference. The’633 Application claims the benefit of the filing date of, and priority to, U.S. Patent Application No. 62/617,438 (the“’438 Application”), filed January 15, 2018, the entire disclosure of which is hereby incorporated herein by reference.

[0003] The Ί 56 Application is also a CIP of U.S. Patent Application No. 16/436,623 (the“’623 Application”), filed June 10, 2019, the entire disclosure of which is hereby incorporated herein by reference. The’623 Application claims the benefit of the filing date of, and priority to, U.S. Patent Application No. 62/755,170, filed November 2, 2018, the entire disclosure of which is hereby incorporated herein by reference.

[0004] The Ί 56 Application is also a CIP of U.S. Patent Application No. 16/100,741 (the “’741 Application”), filed August 10, 2018, 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 March 5, 2018, U.S. Patent Application No. 62/638,681 , filed March 5, 2018, U.S. Patent Application No. 62/637,220, filed March 1 , 2018, U.S. Patent Application No. 62/637,215, filed March 1 , 2018, and U.S. Patent Application No. 62/598,914, filed December 14, 2017, the entire disclosures of which are hereby incorporated herein by reference.

[0005] This application is related to U.S. Patent Application No. 16/855,749 filed April 22, 2020, the entire disclosure of which is hereby incorporated herein by reference. [0006] This application is also related to U.S. Patent Application No. 16/248,648 (the ’648 Application), filed January 15, 2019, the entire disclosure of which is hereby incorporated herein by reference. The’648 Application claims the benefit of the filing date of, and priority to, U.S. Application No. 62/617,443, filed January 15, 2018, the entire disclosure of which is hereby incorporated herein by reference.

[0007] This application is also related to U.S. Patent Application No. 16/801 ,91 1 , filed February 26, 2020, the entire disclosure of which is hereby incorporated herein by reference.

Background

[0008] The present application is related generally to fluid systems and, more particularly, to intelligently controlled fluid systems used in oil and gas operations.

Brief Description of the Drawings

[0009] Figure 1 is a diagrammatic illustration of a system, according to one or more embodiments.

[0010] Figure 2 is a diagrammatic illustration of a zipper module, a fracturing (or“frac”) line, and a wellhead of the system of Figure 1 , according to one or more embodiments.

[0011] Figure 3 is a diagrammatic illustration of a lower zipper valve of the zipper module of Figure 2, according to one or more embodiments.

[0012] Figure 4 is a diagrammatic illustration of an equalization valve of the system of Figure 2, said equalization valve being operably associated with the valve of Figure 3, according to one or more embodiments.

[0013] Figure 5 is a diagrammatic illustration of a hydraulic manifold configured to actuate the valve of Figure 3, one or more other valves similar to said valve, the equalization valve of Figure 4, and one or more other valves similar to said equalization valve, according to one or more embodiments.

[0014] Figure 6 is a flow diagram of a method for implementing one or more embodiments of the present disclosure. [0015] Figure 7 A is a diagrammatic illustration of one or more other wellhead tools or components of the wellhead of Figure 2, said one or more other wellhead tools being in a first operational state or configuration during the execution of Figure 8’s method, according to one or more embodiments.

[0016] Figure 7B is a diagrammatic illustration of the one or more other wellhead tools or components of the wellhead of Figure 2, said one or more other wellhead tools being in a second operational state or configuration during the execution of Figure 8’s method, according to one or more embodiments.

[0017] Figure 7C is a diagrammatic illustration of the one or more other wellhead tools or components of the wellhead of Figure 2, said one or more other wellhead tools being in a third operational state or configuration during the execution of Figure 8’s method, according to one or more embodiments.

[0018] Figure 8 is a flow diagram of a method for implementing one or more embodiments of the present disclosure.

[0019] Figure 9 is a diagrammatic illustration of a system for lubricating process valves, the system including a delivery module and metering modules, according to one or more embodiments of the present disclosure.

[0020] Figure 10 is a diagrammatic illustration of the delivery module of Figure 9, according to one or more embodiments of the present disclosure.

[0021] Figure 11 is a diagrammatic illustration of a first embodiment of one of the metering modules of Figure 9, according to one or more embodiments of the present disclosure.

[0022] Figure 12 is a diagrammatic illustration of lubricator valves operably associated with at least some of the process valves of Figure 9, according to one or more embodiments of the present disclosure.

[0023] Figure 13 is a flow diagram of a method for implementing one or more embodiments of the present disclosure.

[0024] Figure 14 is a diagrammatic illustration of a computing node for implementing one or more embodiments of the present disclosure. Detailed Description

[0025] Referring to Figure 1 , in one or more embodiments, a system generally referred to by the reference numeral 100 is diagrammatically illustrated. The system includes a manifold assembly 105 in fluid communication with a blender 1 10, hydraulic fracturing pumps 1 15a-f, and wellheads 120I-N. The wellheads 120I-N serve as surface terminations for wellbores 125I-N, respectively. The system 100 includes one or more fluid sources 130 in fluid communication with the blender 1 10. The wellheads 120I-N are in fluid communication with the manifold assembly 105 via, for example, zipper modules 1 35I-N and fracturing (or“frac”) lines 140I-N. The zipper modules 135I-N are operably associated with a zipper manifold 145; for example, the zipper modules 135I-N may be interconnected with each other via the zipper manifold 145. In one or more embodiments, the zipper modules 1 35I-N are part of the zipper manifold 145 to which the manifold assembly 105 is operably coupled. In one or more embodiments, the zipper modules 1 35I-N are interconnected. In one or more embodiments, at least one of the zipper modules 1 35I-N is interconnected with at least one other of the zipper modules 135I-N. The frac lines 140i- N couple the zipper modules 1 35I-N, respectively, to the wellheads 120I-N, respectively. In one or more embodiments, the frac lines 140-I-N are part of the zipper manifold 145. The wellhead 120i , the zipper module 135i , and the frac line 140i, in combination, form a frac leg 146i. Similarly, respective sets of the wellheads 1202-N, the zipper modules 1 352-N, and the frac line 1402-N, in combination, form frac legs 1462-N.

[0026] Referring still to Figure 1 , a system for delivering and metering grease to the frac legs 146-I-N is diagrammatically illustrated and generally referred to by the reference numeral 305. In one or more embodiments, the grease 305 is, included, or is part of, the grease system described in the’648 Application. For example, the frac legs 146I-N may include process valves to which the grease system 100 delivers and meters grease, as will be described in more detail below. In one or more embodiments, such process valves are gate valves. The grease system 305 includes a delivery module 315 and metering modules 320I-N. The metering modules 320I-N are each operably associated with, and adapted to be in communication with, the delivery module 315. Likewise, the process valves of the frac legs 146I-N are operably associated with, and adapted to be in communication with, the metering modules 320-I-N, respectively. In operation, to grease the process valves of the frac legs 146I-N, the metering modules 320-I-N are adapted to force grease from the delivery module 315 into the respective process valves, as will be described in more detail below. In one or more embodiments, as in Figure 1 , a controller 180 is adapted to send control signals to the grease system 305 and the frac legs 146i- N, as will be described in more detail below. A user interface 185 is operably coupled to the controller 180 to enable a user to monitor and control the grease system 305 and the frac legs 146I-N, as will be described in more detail below.

[0027] In one or more embodiments, the system 100 and/or the grease system 305 are part of a hydraulic fracturing system, which may be used to facilitate oil and gas exploration and production operations. For example, the system 100 and/or the grease system 305 may be adapted to perform a hydraulic fracturing operation on one or more of the wellbores 125I-N. The embodiments provided herein are not, however, limited to a hydraulic fracturing system, as the system 100 may be used with, or adapted to, a mud pump system, a well treatment system, other pumping systems, one or more systems at the wellheads 120I-N, one or more systems upstream of the wellheads 120I-N, one or more systems downstream of the wellheads 120I-N, and/or one or more other systems associated with the wellheads 120I-N.

[0028] Referring to Figure 2, with continuing reference to Figure 1 , the zipper module 135i, the frac line 140i, and the wellhead 120i are diagrammatically illustrated in detail. In one or more embodiments, the zipper module 135i includes a lower zipper valve 150i, an upper zipper valve 1502, and a fluid connector 155. The lower zipper valve 150i is operably coupled to the zipper manifold 145. The upper zipper valve 1502 is operably coupled to the lower zipper valve 150i opposite the zipper manifold 145. The fluid connector 155 is operably coupled to the upper zipper valve 1502 opposite the lower zipper valve 150i. An equalization valve 160i is in fluid communication with inlet and outlet sides of the lower zipper valve 150i. A pressure sensor 165i is in fluid communication with the inlet side of the lower zipper valve 150i. A pressure sensor 1652 is in fluid communication with the outlet side of the lower zipper valve 150i. Similarly, an equalization valve I6O2 is in fluid communication with inlet and outlet sides of the upper zipper valve 1502. A pressure sensor such as, for example, the pressure sensor 1652 is in fluid communication with the inlet side of the upper zipper valve 1502. A pressure sensor 1653 is in fluid communication with the outlet side of the upper zipper valve 1502.

[0029] In one or more embodiments, the frac line 140i includes frac line valves 1503 and 1504. The frac line valve 1503 is operably coupled to the fluid connector 155 of the zipper module 135i. The frac line valve 1504 is operably coupled to the frac line valve 1503 opposite the fluid connector 155. The frac line 140i is operably coupled between the zipper module 135i and the wellhead 120i. An equalization valve 1603 is in fluid communication with inlet and outlet sides of the frac line valve 1503. A pressure sensor such as, for example, the pressure sensor 1653 is in fluid communication with the inlet side of the frac line valve 1503. A pressure sensor 1654 is in fluid communication with the outlet side of the frac line valve 1503. Similarly, an equalization valve 1604 is in fluid communication with inlet and outlet sides of the frac line valve 1504. A pressure sensor such as, for example, the pressure sensor 1654 is in fluid communication with the inlet side of the frac line valve 1504. A pressure sensor 165s is in fluid communication with the outlet side of the frac line valve 1504.

[0030] In one or more embodiments, the wellhead 120i includes a frac tree 170, a swab valve 1505, and upper master valve 1506, and a lower master valve 1 50N. An inlet side of the lower master valve 150N is in fluid communication with the wellbore 125i . The upper master valve 150b is operably coupled to the lower master valve 1 50N opposite the wellbore 125i. The swab valve 150s is operably coupled to the upper master valve 150b opposite the lower master valve 1 50N. The frac tree 170 is operably coupled to the swab valve 1505 opposite the upper master valve 1506. Alternatively, the frac tree 170 may be operably coupled to the upper master valve 150b opposite the lower master valve 1 50N and the swab valve 150s may be operably coupled to the frac tree 170 opposite the upper master valve 150b. The frac line 140i is operably coupled, via the frac tree 170, to the wellhead 120i. In one or more embodiments, the frac tree 170 is or includes a goat head; in at least one such embodiment, the frac line 140i and one or more additional frac lines substantially similar to the frac line 140i are operably coupled between the zipper module 135i and the goat head so that fluid is communicable from the zipper module 135i to the wellhead 120i through the frac line 140i and the one or more additional frac lines.

[0031] In addition, the wellhead 120i may include one or more other wellhead tools or components 175 such as, for example: one or more wing valves; a tree cap; a tree cap valve; the valve apparatus described in U.S. Patent Application No. 15/487,785 (the“’785 Application”), filed April 14, 2017, and published October 19, 2017 as U.S. Publication No. 2017/0298708, the entire disclosure of which is hereby incorporated herein by reference; the valve apparatus described in U.S. Patent Application No. 16/721 ,203 (the “’203 Application”), filed December 19, 2019, the entire disclosure of which is hereby incorporated herein by reference; the object launching apparatus described in the’633 Application; or any combination thereof. One or more embodiments of the one or more other wellhead tools or components 175 are described in further detail below. Although shown as being operably coupled to the frac tree 170 opposite the swab valve 150s, the one or more other wellhead tools or components 175 may instead be positioned at any location in the wellhead 120i such as, for example, between the wellbore 125i and the lower master valve 1 50N, between the lower master valve 150N and the upper master valve 1506, between the upper master valve 1506 and the swab valve 150s, between the upper master valve 1506 and the frac tree 170, between the frac tree 170 and the swab valve 1505, or any combination thereof.

[0032] An equalization valve 160s is in fluid communication with inlet and outlet sides of the swab valve 150s. A pressure sensor such as, for example, the pressure sensor 165s is in fluid communication with the inlet side of the swab valve 150s. A pressure sensor 1656 is in fluid communication with the outlet side of the swab valve 150s. Similarly, an equalization valve 160Q is in fluid communication with inlet and outlet sides of the upper master valve 1506. A pressure sensor such as, for example, the pressure sensor 165Q is in fluid communication with the inlet side of the upper master valve 1506. A pressure sensor 1657 is in fluid communication with the outlet side of the upper master valve 1506. Similarly, an equalization valve 160N is in fluid communication with inlet and outlet sides of the lower master valve 1 50N. A pressure sensor such as, for example, the pressure sensor 1657 is in fluid communication with the inlet side of the lower master valve 1 50N. A pressure sensor 165N is in fluid communication with the outlet side of the lower master valve 1 50N.

[0033] In one or more embodiments, one or more of the pressure sensors 165I-N includes a bladder or other mechanical buffer to protect the pressure sensor(s) 165I-N from erosions/washout and/or to prevent the pressure sensor(s) 165I-N from plugging off and trapping pressure; in such embodiments, the bladder of other mechanical buffer prevents, or at least reduces, inaccurate readings of line pressure by the pressure sensor(s) 165I-N due to sand or grease plugging process port(s) of the pressure sensor(s) 165I-N.

[0034] In one or more embodiments, one or more of the equalization valves 1601 -N is designed to be resistant to washout and/or abrasive damage to the valve member(s) 2151 -N (shown in Figure 4); accordingly, the equalization valves 1601 -N may incorporate internal materials such as, for example, Stellite, engineered ceramic, Zirconia, or the like to enhance durability and resistance to washout/erosion and to prevent, or at least reduce, sealing issues.

[0035] Although the terms“inlet” and“outlet” used herein may imply a direction of fluid flow from the zipper manifold 145 to the zipper module 135i , from the zipper module 135i to the frac line 140i , from the frac line 140i to the wellhead 120i , and/or from the wellhead 120i to the wellbore 125i, it should be understood that, depending on relative fluid pressures within the system 100, fluid may instead flow in the opposite direction, that is, from the wellbore 125i to the wellhead 120i, from the wellhead 120i to the frac line 140i, from the frac line 140i to the zipper module 135i, and/or from the zipper module to the zipper manifold 145. Accordingly, the term“inlet” may refer to an“outlet” and the term “outlet” may refer to an“inlet.”

[0036] The controller 180 is operably coupled to, and adapted to control, the lower zipper valve 150i , the equalization valve 160i, the upper zipper valve 1502, the equalization valve I 6O2, the frac line valve 1503, the equalization valve I 6O3, the frac line valve 1504, the equalization valve 1604, the swab valve 150s, the equalization valve 160s, the upper master valve 150b, the equalization valve 160b, the lower master valve 1 50N, and the equalization valve 160N, as will be described in more detail below. Further, the controller 180 is operably coupled to, and adapted to monitor, one or more of the pressure sensors 165I-N, that is, the controller 180 is adapted to receive signal(s) from one or more of the pressure sensors 165I-N, as will be described in more detail below. Further still, the controller 180 is operably coupled to, and adapted to control, the one or more other wellhead tools or components 175, as will be described in further detail below. The user interface 185 is operably coupled to the controller 180 to enable a user to monitor and control the zipper module 135i , the frac line 140i , and the wellhead 120i, as will be described in more detail below.

[0037] Referring to Figure 3, with continuing reference to Figure 2, the lower zipper valve 150i is diagrammatically illustrated in detail. In one or more embodiments, the lower zipper valve 150i includes a valve body 190i and a valve member 195i. The valve member 195i extends within the valve body 190i and is actuable between an open configuration and a closed configuration. In the open configuration, the valve member 195i permits fluid flow through the valve body 190i from a high-pressure side (i.e., one of the inlet side or the outlet side of the of the lower zipper valve 150i) to a low-pressure side (i.e., the other of the inlet side or the outlet side of the of the lower zipper valve 150i) of the lower zipper valve 150i, as shown in Figure 3. In the closed configuration, the valve member 195i prevents, or at least partially restricts, fluid flow through the valve body 190i from the high-pressure side to the low-pressure side of the lower zipper valve 150i . An actuator 20CH is operably coupled to the valve member 195i to actuate the valve member 195i within the valve body 190i between the open configuration and the closed configuration. The controller 180 is operably coupled to, and adapted to control, the actuator 200i. In addition to, or instead of, the actuator 200i being controlled by the controller 180, the actuator 200i may be or include a manual actuator that is manually controllable/actuable by an operator (e.g., via hydraulic, electric over hydraulic, or other mechanisms). A position sensor 205i is operably coupled to the actuator 200i to detect a position and/or an orientation of the valve member 195i relative to the valve body 190i . In addition, or instead, the position sensor 205i may be operably coupled to the valve member 195i and/or the valve body 19CH . The controller 180 is operably coupled to, and adapted to monitor, the position sensor 205i, that is, the controller 180 is adapted to receive signal(s) from the position sensor 205i . In one or more embodiments, the feedback provided by the position sensor 205i is analog (i.e. , continuous 0% to 100% open). In addition, or instead, the position sensor 205i may be or include a switch (e.g., having minimum resolutions of 0%, 50%, and 100% open).

[0038] In one or more embodiments, the upper zipper valve 1502, the frac line valve 1503, the frac line valve 1504, the swab valve 150s, the upper master valve 1506, and the lower master valve 150N are substantially similar to, and operate in substantially the same manner as, the lower zipper valve 150i ; therefore, the structure and operation of the upper zipper valve 1502, the frac line valve1503, the frac line valve 1504, the swab valve 150s, the upper master valve 1506, and the lower master valve 1 50N will not be described in more detail. Moreover, the various components of each of the upper zipper valve 1502, the frac line valve 1503, the frac line valve 1504, the swab valve 150s, the upper master valve 1506, and the lower master valve 1 50N may be identified hereinbelow using the same reference numerals as those associated with corresponding components of the lower zipper valve 150i (as set forth above and shown in Figure 3), except that, rather than the subscript“1” used to identify the components of the lower zipper valve 150i , subscripts“2”,“3”,“4”,“5”,“6”, and“N” are used to identify the corresponding components of the upper zipper valve 1502, the frac line valve 1503, the frac line valve 1504, the swab valve 1505, the upper master valve 1506, and the lower master valve 1 50N, respectively.

[0039] Referring to Figure 4, with continuing reference to Figure 2, the equalization valve 160i is diagrammatically illustrated in detail. As discussed above, the equalization valve 160i is in fluid communication with the inlet and outlet sides of the lower zipper valve 150i . In one or more embodiments, the equalization valve 160i includes a valve body 210i and a valve member 215i . The valve member 215i extends within the valve body 210i and is actuable between an open configuration and a closed configuration. In the open configuration, the valve member 215i permits fluid flow through the valve body 210i from a high-pressure side (i.e., one of the inlet side or the outlet side of the of the lower zipper valve 150i) to a low-pressure side (i.e., the other of the inlet side or the outlet side of the lower zipper valve 150i) of the lower zipper valve 150i , as shown in Figure 4. In the closed configuration, the valve member 215i prevents, or at least partially restricts, fluid flow through the valve body 210i from the high-pressure side to the low-pressure side of the lower zipper valve 150i . An actuator 220i is operably coupled to the valve member 215i to actuate the valve member 215i within the valve body 210i between the open configuration and the closed configuration. The controller 180 is operably coupled to, and adapted to control, the actuator 220i . In addition to, or instead of, the actuator 220i being controlled by the controller 180, the actuator 220i may be or include a manual actuator that is manually controllable/actuable by an operator (e.g., via hydraulic, electric over hydraulic, or other mechanisms). A position sensor 225i is operably coupled to the actuator 220i to detect a position and/or an orientation of the valve member 215i relative to the valve body 210i. In addition, or instead, the position sensor 225i may be operably coupled to the valve member 215i and/or the valve body 210-i. The controller 180 is operably coupled to, and adapted to monitor, the position sensor 225i, that is, the controller 180 is adapted to receive signal(s) from the position sensor 225i. In one or more embodiments, the feedback provided by the position sensor 225i is analog (i.e. , continuous 0% to 100% open). In addition, or instead, the position sensor 225i may be or include a switch (e.g., having minimum resolutions of 0%, 50%, and 100% open).

[0040] In one or more embodiments, the equalization valves 1602-N are substantially similar to, and operate in substantially the same manner as, the equalization valve I6O1; therefore, the structure and operation of the equalization valves I6O2-N will not be described in more detail. Moreover, the various components of each of the equalization valves I6O2-N may be identified hereinbelow using the same reference numerals as those associated with corresponding components of the equalization valve I6O1 (as set forth above and shown in Figure 4), except that, rather than the subscript“1” used to identify the components of the equalization valve I6O1, subscripts“2”,“3”,“4”,“5”,“6”, and“N” are used to identify the corresponding components of the equalization valves I6O2-N, respectively.

[0041] Referring to Figure 5, with continuing reference to Figures 2-4, a hydraulic manifold 230 operably associated with the actuators 200I-N and 220I-N is illustrated in detail. More particularly, the hydraulic manifold 230 is operably coupled to the actuators 200I-N of the valves 1 50I-N, respectively, and to the actuators 220I-N of the equalization valves 160-I-N, respectively. The hydraulic manifold 230 facilitates actuation of the actuators 200I-N and 220I-N. A hydraulic power unit (or“HPU”) 235 is operably coupled to the hydraulic manifold 230 and adapted to provide hydraulic fluid to, and to receive hydraulic fluid from, the hydraulic manifold 230. In one or more embodiments, to facilitate the communication of hydraulic fluid between the HPU 235 and the hydraulic manifold 230, the HPU 235 includes a reservoir, a hydraulic pump, and a motor. The controller 180 is operably coupled to, and adapted to control, the hydraulic manifold 230. Specifically, the controller 180 is adapted to actuate, via the hydraulic manifold 230, one or more of the actuators 200I-N and/or 220I-N based at least partially on data/readings received from the pressure sensors165i-N, the position sensors 205I-N, and/or the position sensors 225I-N, as will be described in more detail below. The user interface 185 is operably coupled to the controller 180 and enables a user to modify one or more parameters associated with the controller 180’s actuation of the one or more of the actuators 200I-N and/or 220I-N via the hydraulic manifold 230. In one or more embodiments, the user interface 185 enables a user to take manual control of the controller 180’s actuation of the one or more of the actuators 200I-N and/or 220I-N. In one or more embodiments, the controller 180 may also be operably coupled to, and adapted to control, the HPU 235.

[0042] In one or more embodiments, the system 100 is used to perform a hydraulic fracturing operation. Prior to said hydraulic fracturing operation: the swab valve 150s, the upper master valve 150b, and the lower master valve 1 50N may be open; the lower zipper valve 150i , the upper zipper valve 1502, the frac line valve 1503, and the frac line valve 1504 may be closed; and pressure from the wellbore 125i may be exerted on the frac line valve 1504. In such instances, before initiating the hydraulic fracturing operation, the wellbore pressure exerted on the frac line valve 1504 must be equalized with a pressure of the pumped hydraulic fracturing fluid, that is, the pressure of the hydraulic fracturing fluid pumped into the manifold assembly 105 by the pumps 1 15a-f (shown in Figure 1 ).

[0043] Referring to Figure 6, a method of equalizing the wellbore pressure exerted on the frac line valve 1504 with the pressure of the pumped hydraulic fracturing fluid is generally referred to by the reference numeral 240 and includes: at a step 245, determining, using the controller 180, if a difference between the pressures detected by pressure sensors 1654 and 165s is below a first predetermined threshold; if said difference is above the first predetermined threshold, at a step 250, opening the equalization valve 1604 until said difference is below the first predetermined threshold; if said difference is below the first predetermined threshold, at a step 255, opening the frac line valve 1504; at a step 260, determining, using the controller 180, if a difference between the pressures detected by pressure sensors 1653 and 1654 is below a second predetermined threshold; if said difference is above the second predetermined threshold, at a step 265, opening the equalization valve 1603 until said difference is below the second predetermined threshold; if said difference is below the second predetermined threshold, at a step 270, opening the frac line valve 1503; at a step 275, determining, using the controller 180, if a difference between the pressures detected by pressure sensors 1652 and 1653 is below a third predetermined threshold; if said difference is above the third predetermined threshold, at a step 280, opening the equalization valve I6O2 until said difference is below the third predetermined threshold; if said difference is below the third predetermined threshold, at a step 285, opening the upper zipper valve 1502; at a step 290, determining, using the controller 180, if a difference between the pressures detected by pressure sensors 165i and 1652 is below a fourth predetermined threshold; if said difference is above the fourth predetermined threshold, at a step 295, opening the equalization valve I 6O1 until said difference is below the fourth predetermined threshold; and, if said difference is below the fourth predetermined threshold, at a step 300, opening the lower zipper valve 150i .

[0044] In one or more embodiments of the method 240, at least one of the first, second, third, and fourth predetermined thresholds is substantially identical to at least one other of the first, second, third, and fourth thresholds. In other embodiments of the method 240, at least one of the first, second, third, and fourth predetermined thresholds is different from at least one other of the first, second, third, and fourth predetermined thresholds. In one or more embodiments, the first, second, third, and/or fourth thresholds is/are user defined. [0045] In one or more embodiments, the step(s) 245, 260, 275, and/or 290 may be referred to as “intelligent lockout” steps that disallow a requested actuation of the corresponding valve(s) I 6O1 -4 due to excessive differential pressure(s) thereacross, as measured by corresponding pair(s) of the pressure sensors 165i-s. In addition to, or instead of, performing the“intelligent lockout” steps of the method 240, the system 100 may include one or more mechanical interlocks designed to utilize fluid pressure from the inlet and outlet sides of a particular to-be-actuated valve I 6O1 , 2, 3, or 4 to block hydraulic flow (i.e., preventing said 16O1 , 2, 3, or 4 valve from opening) unless the pressure differential between said inlet and outlet sides is balanced.

[0046] In one or more embodiments, the step(s) 245, 260, 275, and/or 290 may be implemented via software stored on the controller 180 (or elsewhere) so that, when an operator desires to open one or more of the valves I 6O1-4, the software only allows such opening of the valve(s) I 6O1 -4 if the differential pressure(s) across the valve(s) I 6O1-4 are less than the corresponding predetermined threshold(s) (i.e. , the first, second, third, and/or fourth thresholds). In addition, or instead, such software may include combinational logic requiring various other condition(s) to be met prior to actuation of a particular to-be-actuated valve I 6O1, 2, 3, or 4, such as, for example: the pressure in the wellbore 125I-N with which the to-be-actuated valve I 6O1, 2, 3, or 4 is associated must be below a predetermined threshold, above a predetermined threshold, or within a predetermined range; the pressure in one or more of the other wellbores 125I-N in the system 100 must be below a predetermined threshold, above a predetermined threshold, or within a predetermined range; the state of the to-be-actuated valve I 6O1, 2, 3, or 4 must be open, closed, or transitioning; the state(s) of the one or more other valves 16O1, 2, 3, or 4 in the system 100 must be open, closed, or transitioning (e.g., the other valve(s) I6O1, 2, 3, or 4 must be opened/closed/transitioning prior to actuation of the to-be-actuated valve 1 60-1, 2, 3, or 4); one or more other conditions must be met; or any combination thereof.

[0047] In one or more embodiments, certain steps of the method 240 are performed in the following sequential order: step 245, step 255, step 260, step 270, step 275, step 285, step 290, and step 300. [0048] In one or more embodiments, certain steps of the method 240 are performed in the following sequential order: step 245, step 255, step 260, step 270, step 290, step 300, step 275, and step 285.

[0049] In one or more embodiments, certain steps of the method 240 are performed in the following sequential order: step 245, step 255, step 275, step 285, step 260, step 270, step 290, and step 300.

[0050] In one or more embodiments, certain steps of the method 240 are performed in the following sequential order: step 245, step 255, step 275, step 285, step 290, step 300, step 260, and step 270.

[0051] In one or more embodiments, certain steps of the method 240 are performed in the following sequential order: step 245, step 255, step 290, step 300, step 260, step 270, step 275, and step 285.

[0052] In one or more embodiments, certain steps of the method 240 are performed in the following sequential order: step 245, step 255, step 290, step 300, step 275, step 285, step 260, and step 270.

[0053] In one or more embodiments, certain steps of the method 240 are performed in the following sequential order: step 260, step 270, step 245, step 255, step 275, step 285, step 290, and step 300.

[0054] In one or more embodiments, certain steps of the method 240 are performed in the following sequential order: step 260, step 270, step 245, step 255, step 290, step 300, step 275, and step 285.

[0055] In one or more embodiments, certain steps of the method 240 are performed in the following sequential order: step 260, step 270, step 275, step 285, step 245, step 255, step 290, and step 300.

[0056] In one or more embodiments, certain steps of the method 240 are performed in the following sequential order: step 260, step 270, step 275, step 285, step 290, step 300, step 245, and step 255.

[0057] In one or more embodiments, certain steps of the method 240 are performed in the following sequential order: step 260, step 270, step 290, step 300, step 245, step 255, step 275, and step 285. [0058] In one or more embodiments, certain steps of the method 240 are performed in the following sequential order: step 260, step 270, step 290, step 300, step 275, step 285, step 245, and step 255.

[0059] In one or more embodiments, certain steps of the method 240 are performed in the following sequential order: step 275, step 285, step 245, step 255, step 260, step 270, step 290, and step 300.

[0060] In one or more embodiments, certain steps of the method 240 are performed in the following sequential order: step 275, step 285, step 245, step 255, step 290, step 300, step 260, and step 270.

[0061] In one or more embodiments, certain steps of the method 240 are performed in the following sequential order: step 275, step 285, step 260, step 270, step 245, step 255, step 290, and step 300.

[0062] In one or more embodiments, certain steps of the method 240 are performed in the following sequential order: step 275, step 285, step 260, step 270, step 290, step 300, step 245, and step 255.

[0063] In one or more embodiments, certain steps of the method 240 are performed in the following sequential order: step 275, step 285, step 290, step 300, step 245, step 255, step 260, and step 270.

[0064] In one or more embodiments, certain steps of the method 240 are performed in the following sequential order: step 275, step 285, step 290, step 300, step 260, step 270, step 245, and step 255.

[0065] In one or more embodiments, certain steps of the method 240 are performed in the following sequential order: step 290, step 300, step 245, step 255, step 260, step 270, step 275, and step 285.

[0066] In one or more embodiments, certain steps of the method 240 are performed in the following sequential order: step 290, step 300, step 245, step 255, step 275, step 285, step 260, and step 270.

[0067] In one or more embodiments, certain steps of the method 240 are performed in the following sequential order: step 290, step 300, step 260, step 270, step 245, step 255, step 275, and step 285. [0068] In one or more embodiments, certain steps of the method 240 are performed in the following sequential order: step 290, step 300, step 260, step 270, step 275, step 285, step 245, and step 255.

[0069] In one or more embodiments, certain steps of the method 240 are performed in the following sequential order: step 290, step 300, step 275, step 285, step 245, step 255, step 260, and step 270.

[0070] In one or more embodiments, certain steps of the method 240 are performed in the following sequential order: step 290, step 300, step 275, step 285, step 260, step 270, step 245, and step 255.

[0071] In one or more embodiments, prior to said hydraulic fracturing operation: the lower zipper valve 150i , the upper zipper valve 1502, the frac line valve 1503, the frac line valve 1504, the swab valve 150s, the upper master valve 150b, and the lower master valve 1 50N may be closed; and pressure from the wellbore 125i may be exerted on the lower master valve 1 50N. In such instances, in addition to the steps 245, 250, 255, 260, 265, 270, 275, 280, 285, 290, 295, and 300, the method 240 may further include: an additional step (substantially similar to the steps 245, 260, 275, and 290) of determining, using the controller 180, if a difference between the pressures detected by pressure sensors 1657 and 165N is below a fifth predetermined threshold; if said difference is above the fifth predetermined threshold, an additional step (substantially similar to the steps 250, 265, 280, and 295) of opening the equalization valve 160N until said difference is below the fifth predetermined threshold; if said difference is below the first predetermined threshold, an additional step (substantially similar to the steps 255, 270, 285, and 300) of opening the lower master valve 1 50N; an additional step (substantially similar to the steps 245, 260, 275, and 290) of determining, using the controller 180, if a difference between the pressures detected by pressure sensors 165b and 1657 is below a sixth predetermined threshold; if said difference is above the sixth predetermined threshold, an additional step (substantially similar to the steps 250, 265, 280, and 295) of opening the equalization valve 160b until said difference is below the sixth predetermined threshold; if said difference is below the sixth predetermined threshold, an additional step (substantially similar to the steps 255, 270, 285, and 300) of opening the upper master valve 150b; an additional step (substantially similar to the steps 245, 260, 275, and 290) of determining, using the controller 180, if a difference between the pressures detected by pressure sensors 165s and 165b is below a seventh predetermined threshold; if said difference is above the seventh predetermined threshold, an additional step (substantially similar to the steps 250, 265, 280, and 295) of opening the equalization valve 160s until said difference is below the seventh predetermined threshold; and if said difference is below the seventh predetermined threshold, an additional step (substantially similar to the steps 255, 270, 285, and 300) of opening the swab valve 150s. Similar to the sequential order in which the steps 245, 250, 255, 260, 265, 270, 275, 280, 285, 290, 295, and 300 may be performed, the above-described additional steps of the method 240 may be performed in any sequential order before, during, or after the steps 245, 250, 255, 260, 265, 270, 275, 280, 285, 290, 295, and/or 300 are performed.

[0072] In one or more embodiments of the method 240, at least one of the first, second, third, fourth, fifth, sixth, and seventh predetermined thresholds is substantially identical to at least one other of the first, second, third, fourth, fifth, sixth, and seventh thresholds. In other embodiments of the method 240, at least one of the first, second, third, fourth, fifth, sixth, and seventh predetermined thresholds is different from at least one other of the first, second, third, fourth, fifth, sixth, and seventh predetermined thresholds. In one or more embodiments, the first, second, third, fourth, fifth, sixth, and/or seventh thresholds is/are user defined.

[0073] In various embodiments of the method 240, prior to said hydraulic fracturing operation, each of the lower zipper valve 150i, the upper zipper valve 1502, the frac line valve 1503, the frac line valve 1504, the swab valve 150s, the upper master valve 1506, and/or the lower master valve 1 50N may be open, closed, or transitioning; accordingly, one or more of the steps 245, 250, 255, 260, 265, 270, 275, 280, 285, 290, 295, 300, and/or one or more of the other above-described steps of the method 240 may be omitted as needed so that execution of the method 240 equalizes the wellbore pressure(s) with the pressure of the pumped hydraulic fracturing fluid.

[0074] In one or more embodiments, the zipper modules 1 352-N, the frac lines 1 402-N, and the wellheads 1202-N are substantially similar to, and operate in substantially the same manner as, the zipper module 135i , the frac line 140i , and the wellhead 120i ; therefore, the structure and operation of the zipper modules 1 352-N, the frac lines 1 402-N, and the wellheads 1 202-N will not be described in more detail. Moreover, the various components of each of the zipper modules 1352-N, the frac lines 1402-N, and the wellheads 1 202-N may be identified hereinbelow using the same reference numerals as those associated with corresponding components of the zipper module 135i, the frac line 140i, and the wellhead 120i (as set forth above and shown in Figures 2-4).

[0075] In one or more embodiments, the controller 180 is operably coupled to, and adapted to control, various components of the zipper modules 1 352-N, the frac lines 1402- N, and the wellheads 1 202-N (i.e. , the frac legs 1 462-N) in a substantially similar manner as the manner in which the controller 180 is operably coupled to the lower zipper valve 150i , the equalization valve I 6O1 , the upper zipper valve 1502, the equalization valve I 6O2, the frac line valve 1503, the equalization valve I 6O3, the frac line valve 1504, the equalization valve 1604, the swab valve 150s, the equalization valve 160s, the upper master valve 1506, the equalization valve 160b, the lower master valve 1 50N, and the equalization valve 1 60N. AS a result, in addition to monitoring and controlling the zipper module 135i , the frac line 140i, and the wellhead 120i (i.e., the frac leg 146i), the user interface 185 enables a user to monitor and control the zipper modules 1 352-N, the frac lines 1 402-N, and the wellheads 1 202-N (i.e., the frac legs 1 462-N). Alternatively, one or more other controllers substantially similar to the controller 180 may be operably coupled to, and adapted to control, the various components of the zipper modules 1 352-N, the frac lines 1 402-N, and the wellheads 1 202-N. In such instances, the user interface 185 or one or more other user interfaces substantially similar to the user interface 185 may be operably coupled to the one or more other controllers to enable a user to monitor and control the zipper modules 1 352-N, the frac lines 1 402-N, and the wellheads 1 202-N.

[0076] In one or more embodiments, the operation of the system 100 and/or the execution of the method 240 allows an operator to remotely control one or more of the valves 150i-2 of the zipper modules 1 35I-N, one or more of the valves 1503-4 of the frac lines 1 40I -N, and/or one or more of the valves 150s-7 of the wellheads 1 20I -N to conduct various wellbore operations on each of the wellbores 1 25I-N. AS a result, the operation of the system 100 and/or the execution of the method 240 eliminates the need for personnel to enter the“red zone” (i.e. , a predetermined area in the vicinity of the valve(s) 150I-N deemed to be hazardous, unsafe, or less safe) in order to actuate the valve(s) 1 50I-N. AS described above, during such remote control of the valve(s) 1 50I-N, the corresponding position sensor(s) 205I-N send signal(s) to the controller 180 so that the controller can verify that the valve(s) 1 50I-N are in the correct state to perform the desired wellbore operation (e.g., to hydraulically fracture one or more of the wellbores 125I-N, to perform wireline operations, to grease the valve(s) 1 50I-N, to perform“flow back” on one or more of the wellbores 125I-N, to perform coiled tubing operations, to perform another operation, or any combination thereof). In one or more embodiments, the operation of the system 100 and/or the execution of the method 240 provides feedback to an operator so that the operator can identify leaks in the zipper manifold 145, the zipper modules 135I-N, the frac lines 140I-N, the wellheads 120I-N, or elsewhere in the system 100 by monitoring the pressure sensor(s) 165I-N and/or the position sensor(s) 205I-N and/or 225I-N.

[0077] Referring to Figures 7A-7C, in one or more embodiments, the one or more other wellhead tools or components 175 introduced in connection with Figure 2 include a valve 301 a, a latch 301 b, a launcher 301 c, and a lubricator 301 d. For example, the one or more other wellhead tools or components 175 may be, include, or be part of the system described in the Ί 56 Application. The valve 301 a is operably coupled to the wellhead 120i , which wellhead 120i is the surface termination of the wellbore 125i. In one or more embodiments, the valve 301 a is, includes, or is part of the valve apparatus described in the ’785 Application, the ’203 Application, or both. The valve 301 a is controlled by the controller 180. As discussed above, the user interface 185 communicates signals to, and receives signals from, the controller 180. The latch 301 b is operably coupled to the valve 301 a, opposite the wellhead 120i . The launcher 301 c is operably coupled to the latch 301 b, opposite the valve 301 a. In one or more embodiments, the launcher 301 c is, includes, or is part of the launcher described in the Ί 56 Application. Although not shown in Figure 1 , in one or more embodiments, a blowout preventer (BOP) may be operably coupled to the launcher 301 c, opposite the latch 301 b. [0078] The lubricator 301 d is extendable through the launcher 301 c (and the BOP attached thereto in certain embodiments) and, when so extended, attachable to the latch 301 b. More particularly, the controller 180 communicates signals to a hydraulic manifold, which signals cause the hydraulic manifold to communicate hydraulic fluid to, and/or receive hydraulic fluid from, the latch 301 b to thereby operate the latch 301 b. Subsequently, the lubricator 301 d is detachable from the latch 301 b in a similar manner and, when so detached, retractable from the launcher 301 c. In one or more embodiments, the latch 301 b, the lubricator 301 d, and the process of attaching/detaching the lubricator 301 d to/from the latch 301 b are described in the’623 Application, the’741 Application, or a combination thereof.

[0079] Referring to Figure 8, with continuing reference to Figures 7A-7C, in one or more embodiments, a method of launching an object into the wellbore 125i is generally referred to by the reference numeral 302. In one or more embodiments, the method 302 is executed using the one or more other wellhead tools or components 175. In at least one such instance, the launcher 301 c is connected to the latch 301 b. Although not shown in Figures 7A-7C, in one or more embodiments, a blowout preventer (BOP) may be operably coupled to the launcher 301 c, opposite the latch 301 b. The method 302 includes, at a step 303a, extending the lubricator 301 d through a central passageway of the launcher 301 c. More particularly, the lubricator 301 d is displaced in a direction 304a (as shown in Figure 7 A), through the central passageway of the launcher 301 c (and the BOP attached thereto in certain embodiments), and into a central passageway of the latch 301 b (as shown in Figure 7B). At a step 303b, the lubricator 301 d is attached to the latch 301 b. In one or more embodiments, the step 303b is executed after the step 303a, and while the lubricator 301 d extends through the central passageway of the launcher 301 c. More particularly, the step 303b is executable when the lubricator 301 d extends through the central passageway of the launcher and into the central passageway of the latch 301 b (as shown in Figure 7B). In one or more embodiments, the latch 301 b, the lubricator 301 d, and the process of attaching the lubricator 301 d to the latch 301 b are described in the’623 Application, the’741 Application, or a combination thereof. [0080] At a step 303c, a first wellbore operation (e.g., a perforating operation) is performed while the lubricator 301 d is attached to the latch 301 b. In one or more embodiments, the step 303c is executable by deploying a downhole tool (not shown; e.g., a plug and perforating guns) from the lubricator 301 d on a conveyance string (e.g., wireline) while the lubricator 301 d is attached to the latch 301 b. More particularly, the downhole tool passes through the central passageway of the latch 301 b, through a central passageway of the valve 301 a, through a central passageway of the wellhead 120i , and into the wellbore 125i . In one or more embodiments, the valve 301 a and the process of passing the downhole tool through the valve 301 a and into the wellbore 125i are described in the 785 Application, the’203 Application, or both.

[0081] For example, the controller 180 may receive a signal from a sensor indicating that the valve 301 a is open, thereby determining that wireline is in the wellbore 125i . After the controller 180 receives such a signal, the controller 180 may then“lock-out” actuation of one or more of the valves 1 50I-N (e.g., the valves 1 50S-N of the wellhead 120i) until the controller 180 receives another signal (or ceases to receive the original signal) from the sensor indicating that the valve 301 a is closed, thereby determining that the wireline is out of the wellbore 125i . Such a process helps to prevent users from inadvertently cutting the wireline via actuation of one or more of the valves 150I-N, which is a common failure. A manual override of this process may be utilized just in case a user needs to intentionally cut the wireline for emergency purposes.

[0082] In those embodiments in which the downhole tool includes the plug and perforating guns, the plug is set, the perforating guns are fired, and the spent perforating guns are retrieved from the wellbore 125i and back into the lubricator 301 d to complete execution of the step 303c. At a step 303d, the lubricator 301 d is detached from the latch 301 b. In one or more embodiments, the step 303d is executed after the first wellbore operation is performed at the step 303c (e.g., after the spent perforating guns are retrieved from the wellbore 125i and back into the lubricator 301 d). In one or more embodiments, the latch 301 b, the lubricator 301 d, and the process of detaching the lubricator 301 d from the latch 301 b are described in the ’623 Application, the 741 Application, or a combination thereof. [0083] At a step 303e, the lubricator 301 d is retracted from the central passageway of the launcher 301 c. In one or more embodiments, the step 303e is executed after the step 303d. More particularly, the lubricator 301 d is displaced in a direction 304b (as shown in Figure 7C) to execute the step 303e. At a step 303f, an object is launched from the launcher 301 c so that the object enters the wellbore 125i. In one or more embodiments, the step 303f is executed after the step 303e. The execution of the step 303f causes the object to pass through the valve 301 a before entering the wellbore 125i. In one or more embodiments, the valve 301 a and the process of passing the object therethrough is described in the 785 Application, the’203 Application, or both. Finally, at a step 303g, a second wellbore operation (e.g., a hydraulic fracturing operation) is performed. In one or more embodiments, the step 303g is executed after the step 303f. In those embodiments in which the second wellbore operation is a hydraulic fracturing operation, a hydraulic fracturing fluid is pumped into the wellbore 125i via the frac leg 146i to facilitate execution of the step 303g.

[0084] Referring to Figure 9, with continuing reference to Figures 1 and 2, in one or more embodiments, the grease system 305 is used to deliver and meter grease to process valves 31 0I-N used in oil and gas operations. For example, the process valves 310-I-N to which the grease system 305 delivers and meters grease may be, include, or be part of the lower zipper valve 150i , the equalization valve 160i , the upper zipper valve 1502, the equalization valve I 6O2, the frac line valve 1503, the equalization valve I 6O3, the frac line valve 1504, the equalization valve 16O4, the swab valve 150s, the equalization valve 160s, the upper master valve 1506, the equalization valve 1606, the lower master valve 150N, the equalization valve 160N, or any combination thereof. As discussed above, the grease system 305 includes the delivery module 315 and the metering modules 320i- N. The metering modules 320I-N are each operably associated with, and adapted to be in communication with, the delivery module 315. Likewise, the process valves 31 0I-N are operably associated with, and adapted to be in communication with, the metering modules 320I-N, respectively. In operation, to grease the process valves 31 0I-N, the metering modules 320I-N are adapted to force grease from the delivery module 315 into the respective process valves 31 0-I-N. [0085] Referring to Figure 10 with continuing reference to Figure 9, in one or more embodiments, the delivery module 315 includes a fluid power source 325 and a grease container 330. The fluid power source 325 stores a power fluid for forcing grease from the grease container 330 into the process valves 310-I-N, as will be described in more detail below. A fluid transport device 335 is operably associated with the fluid power source 325. The fluid transport device 335 can be a pump or a compressor, depending on the nature of the power fluid being used. In addition, or instead, the fluid transport device 335 may be or include a hydraulic power unit (“FIPU”) accumulator. In any case, the fluid transport device 335 is adapted to transport the power fluid from the fluid power source 325 to the metering modules 320-I-N. A pressure sensor 340 is operably associated with the fluid transport device 335. The pressure sensor 340 is adapted to detect the pressure of the power fluid discharged from the fluid transport device 335. In addition to providing the power fluid transported to the metering modules 320I-N, the fluid power source 325 is also adapted to receive recycled power fluid from the metering modules 320I-N.

[0086] The grease container 330 stores grease. A grease measuring device 345 such as, for example, a load cell (e.g., a scale) is operably associated with the grease container 330. The grease measuring device 345 may be adapted to measure a mass of the grease container 330 to keep track of the amount of grease that has been used and how much is remaining. Flowever, although described herein as a load cell, the grease measuring device 345 may be any suitable device capable of monitoring the amount of grease in the grease container 330 such as, for example, a ranging device, a linear position transducer, an optical/laser device, or the like that measures a level of the grease within the grease container 330. A fluid transport device 350 is operably associated with the grease container 330. The fluid transport device 350 can be a pump or a compressor, depending on the nature of the power fluid being used. In addition, or instead, the fluid transport device 350 may be or include a hydraulic power unit (“FIPU”) accumulator. In any case, the fluid transport device 350 is adapted to transport grease from the grease container 330 to the metering modules 320I-N. A pressure sensor 355 is operably associated with the fluid transport device 350. The pressure sensor 355 is adapted to detect the pressure of the grease discharged from the fluid transport device 350. In addition to providing the grease transported to the metering modules 320-I-N, the grease container 330 is also adapted to receive recycled grease from the metering modules 320I-N. TO this end, a return valve 360 is operably associated with the grease container 330 and adapted to selectively permit communication of the recycled grease from the metering modules 320i- N to the grease container 330.

[0087] In one or more embodiments, as in Figure 10, the grease system 305 also includes the controller 180. The controller 180 is adapted to send control signals to the fluid transport devices 335 and 350 and the return valve 360. In addition, the controller 180 may receive operating speed data from the fluid transport devices 335 and 350 and/or valve position data from the return valve 360. The controller 180 is also adapted to receive data/readings from the pressure sensors 340 and 355 (e.g., pressure data) and the grease measuring device 345 (e.g., grease measurement data).

[0088] In one or more embodiments, the metering modules 320I-N are substantially identical to each other and, therefore, in connection with Figure 1 1 , only the metering module 320i will be described in detail below; however, the description below also applies to the metering modules 3202-N. Referring to Figure 1 1 , with continuing reference to Figures 9 and 10, in one or more embodiments, to meter the amount of grease to a particular one of the process valves 310i , the metering module 320i includes a grease metering device 365 such as, for example, a grease pump. In one or more embodiments, as in Figure 1 1 , the grease metering device 365 includes a piston 370, a power cylinder 375, and a grease cylinder 380.

[0089] The piston 370 includes a head portion 385 and a rod portion 390. The head portion 385 is slidably disposed in the power cylinder 375 and divides the power cylinder 375 into chambers 395 and 400. The rod portion 390 extends from the head portion 385 into the grease cylinder 380 so that, as the head portion 385 travels back and forth in the power cylinder 375, the rod portion 390 extends at least partially into, and retracts at least partially out of, the grease cylinder 380. The piston 370 may be displaced within the power cylinder 375 via hydraulic or pneumatic power; thus, in one or more embodiments, the power fluid stored by the fluid power source 325 is hydraulic or pneumatic. In addition, or instead, electric or gas power may be utilized to displace the piston 370.

[0090] In one or more embodiments, as in Figure 1 1 , a control valve 405 is operably associated with the power cylinder 375. The control valve 405 is adapted to receive the power fluid from the fluid transport device 335. To stroke the piston 370 in a direction 410, the control valve 405 is adapted to communicate power fluid from the fluid transport device 335 to the chamber 395 and, at the same time, to communicate power fluid from the chamber 400 back to the fluid power source 325. Similarly, to stroke the piston 370 in a direction 415, which is opposite the direction 410, the control valve 405 is adapted to communicate power fluid from the fluid transport device 335 to the chamber 400 and, at the same time, to communicate power fluid received from the chamber 395 back to the fluid power source 325. In addition, the pressure of the grease within the grease cylinder 380 forces the piston 370 in the direction 415. In one or more embodiments, the force exerted on the piston 370 by the grease within the grease cylinder 380 is sufficient by itself to stroke the piston 370 in the direction 415. Accordingly, to ensure that the grease cylinder 380 is filled with grease before being stroked in the direction 410, the force exerted on the piston 370 by the grease within the grease cylinder 380 may itself be relied on to stroke the piston 370 in the direction 415. In one or more embodiments, the fluid power source 325, the fluid transport device 335, the pressure sensor 340, the power cylinder 375, the control valve 405, or any combination thereof, may collectively be referred to herein as an“actuator” (i.e. , hydraulic- or pneumatic-powered) for stroking the piston 370 back and forth within the grease cylinder 380. However, in addition, or instead, another“actuator” may also be used to stroke the piston 370 back and forth within the grease cylinder 380 such as, for example, an electric- or gas-powered actuator.

[0091] A cycle counter 420 is operably associated with the power cylinder 375. The cycle counter 420 may be or include limit switch(es) or other sensor(s) operably associated with the actuator to give analog or other linear position feedback. In any case, the cycle counter 420 is adapted to count the strokes of the piston 370 within the power cylinder 375. In one or more embodiments, the cycle counter 420 is capable of detecting partial strokes of the piston 370 to further enable precise greasing of the process valves 310i . As a result, if so desired, the grease system 305 is capable of partially greasing the process valves 310i by allowing an operator to enter the“desired percentage” of grease required. In one or more embodiments, as in Figure 1 1 , the controller 180 is adapted to send control signals to the control valve 405. In addition, the controller 180 may receive valve position data from the control valve 405. The controller 180 is also adapted to receive data/readings (e.g., stroke count data) from the cycle counter 420.

[0092] A check valve 425 is operably associated with an inlet 426 of the grease cylinder 380 and is adapted to communicate grease from the fluid transport device 350 to the grease cylinder 380 while preventing, or at least reducing, any backflow of the grease through the check valve 425. As a result, when the piston 370 is stroked in the direction 415, the rod portion 390 is retracted at least partially out of the grease cylinder 380 and the check valve 425 permits grease to be drawn into the grease cylinder 380 via the inlet 426. At the same time, a check valve 430 prevents grease from being drawn into the grease cylinder 380 via an outlet 431 . The check valve 430 is operably associated with the outlet 431 of the grease cylinder 380 and is adapted to communicate grease from the grease cylinder 380 to the process valves 310i while preventing, or at least reducing, any backflow of the grease through the check valve 430. As a result, when the piston 370 is stroked in the direction 410, the rod portion 390 is extended at least partially into the grease cylinder 380 and the check valve 430 permits grease to be forced out of the grease cylinder 380 via the outlet 431 . At the same time, the check valve 425 prevents grease from being forced out of the grease cylinder 380 via the inlet 426. In one or more embodiments, the check valve 430 is biased to the closed position with more force (e.g., tighter springs) than that of the check valve 425 in order to maintain the pressure of the grease within the grease cylinder 380. For example, springs in the check valve 430 can be tuned to a desired cracking pressure (e.g., about 1000 psi) to determine the pressure of the grease within the grease cylinder 380.

[0093] In one or more embodiments, the grease metering device 365 is“double-acting” and includes a second grease cylinder substantially identical to the grease cylinder 380 and a second rod portion substantially identical to the rod portion 390; the second rod portion extends from the head portion 385 into the second grease cylinder so that, as the head portion 385 travels back and forth in the power cylinder 375, the second rod portion extends at least partially into, and retracts at least partially out of, the second grease cylinder.

[0094] Referring to Figure 12 with continuing reference to Figures 9-1 1 , in one or more embodiments, the process valves 310i are adapted to be in communication with the metering module 320i via lubricator valves 435I-N, respectively. In one or more embodiments, the lubricator valves 435I-N are part of the metering module 320i. Similarly, the process valves 31 02-N may be adapted to be in communication with the metering modules 3202-N, respectively, via lubricator valve(s) substantially identical to the lubricator valves 435I-N. The lubricator valves 435I-N are adapted to selectively communicate grease from the grease cylinder 380 (shown in Figure 1 1 ) to respective ones of the process valves 310i (shown in Figure 12). In one or more embodiments, as in Figure 12, the controller 180 is adapted to send control signals to the lubricator valves 435-I-N. In addition, the controller 180 may receive valve position data from the lubricator valves 435I-N.

[0095] Alternatively, in one or more embodiments, the grease metering device 365 may be omitted and replaced with flow meters that are operably associated with respective ones of the process valves 310i (and thus respective ones of the lubricator valves 435i- N; in such embodiments, the controller 180 receives feedback from the flow meters and actuates the lubricator valves 435I-N to meter a desired amount of grease to the process valves 310i using the fluid transport device 350. In one or more embodiments, the grease system 305 further includes one or more pressure sensors located downstream from the check valve 430 (e.g., to monitor pressure within the process valves 310i); as a result, using data/readings obtained from these one or more pressure sensors, the controller 180 can ensure that the greasing pressure is greater than the pressure within the process valves 310i. Additional valves may also be added downstream from the check valve 430 to provide double barriers to prevent, or at least reduce, any leakage of process fluid from the process valve.

[0096] Referring collectively to Figures 9-12, in operation, the fluid transport device 335 transports power fluid from the fluid power source 325 to the control valve 405 of the metering module 320i . During the transporting of the power fluid to the control valve 405, the controller 180 communicates control signals to the fluid transport device 335 and receives data/readings from the pressure sensor 340. As a result, the controller 180 can adjust the flow of the power fluid to the control valve 405 using the fluid transport device 335 and monitor the pressure of the power fluid exiting the fluid transport device 335 using the pressure sensor 340. The control valve 405 actuates the piston 370 within the power cylinder 375. To actuate the piston 370 in the direction 410 within the power cylinder 375, the control valve 405 communicates power fluid from the 130 to the chamber 395 and, at the same time, communicates power fluid from the chamber 400 back to the fluid power source 325. Conversely, to actuate the piston 370 in the direction 415 within the power cylinder 375, the control valve 405 communicates power fluid from the fluid transport device 335 to the chamber 400 and, at the same time, communicates power fluid from the chamber 395 back to the fluid power source 325. During the actuation of the piston 370 within the power cylinder 375, the controller 180 communicates control signals to the control valve 405 and receives data/readings from the cycle counter 420. As a result, the controller 180 can stroke the piston 370 back and forth within the power cylinder 375 using the control valve 405 and count the strokes of the piston 370 back and forth within the power cylinder 375 using the cycle counter 420. In other embodiments, in addition, or instead, electric or gas power may be utilized to actuate the piston 370.

[0097] The fluid transport device 350 transports grease from the grease container 330 to the inlet 426 of the grease cylinder 380. During the transporting of the grease to the grease cylinder 380, the controller 180 communicates control signals to the fluid transport device 350 and receives data/readings from the pressure sensor 355. As a result, the controller 180 can adjust the flow of the grease to the grease cylinder 380 using the fluid transport device 350 and monitor the pressure of the grease exiting the fluid transport device 350 using the pressure sensor 355. As the piston 370 is actuated in the direction 415, the grease is drawn into the grease cylinder 380 through the inlet 426. The transporting of the grease to the grease cylinder 380 using the fluid transport device 350 allows the grease to be more efficiently and completely drawn into the grease cylinder 380 through the inlet 426 as the piston 370 is actuated in the direction 415. Conversely, as the piston 370 is actuated in the direction 410, the grease is forced out of the grease cylinder 380 through the outlet 431 . The lubricator valves 435I-N selectively communicate the grease forced out of the grease cylinder 380 to respective ones of the process valves 310i . In addition, the return valve 360 selectively communicates the grease forced out of the grease cylinder 380 back to the grease container 330.

[0098] The controller 180 communicates control signals to the return valve 360 and the lubricator valves 435I-N. AS a result, the controller 180 can selectively actuate the return valve 360 and the lubricator valves 435I-N to determine: whether the grease forced out of the grease cylinder 380 is communicated back to the grease container 330; and/or which of the process valves 310i receives the grease forced out of the grease cylinder 380. For example, if the controller 180 closes the return valve 360, opens one of the lubricator valves 435I-N, and closes the remaining lubricator valves 435I-N, the grease forced out of the grease cylinder 380 will be communicated to the process valve 310i that is operably associated with the opened one of the lubricator valves 435I-N. For another example, if the controller 180 opens the return valve 360 and closes the lubricator valves 435I-N, the grease forced out of the grease cylinder 380 will be communicated back to the grease container 330. Alternatively, the return valve 360 could bypass the grease cylinder 380 by communicating grease back to the grease container 330 before the grease passes through the check valve 425.

[0099] The volume of grease forced out of the grease cylinder 380 with each stroke of the piston 370 can be determined via measurement or calculation (e.g., by multiplying the cross-sectional area of the rod portion 390 by the length of the piston 370’s stroke); as a result, by controlling and/or monitoring the control valve 405, the cycle counter 420, the lubricator valves 435I-N, the return valve 360, or any combination thereof, the controller 180 meters a desired amount of grease to each of the process valves 310i . In one or more embodiments, the desired amount of grease metered to each of the process valves 310i can be specifically tailored according to greasing volume and/or frequency guidelines provided, for example, by the manufacturer(s) of the process valves 310i and stored in a database accessible by the controller 180. In addition, or instead, the desired amount of grease metered to each of the process valves 310i may be provided by a user via a user interface (HMI) connected to the controller 180; if so desired, the amount of grease metered to each of the process valves 310i can be changed during a job. In addition, by controlling and/or monitoring the fluid transport devices 335 and 350 and the pressure sensors 340 and 355, the controller 180 regulates the flow of the power fluid and the grease within the grease system 305.

[0100] In one or more embodiments, the controller 180 is further adapted to receive data/readings from a pressure sensor 436 (shown in Figure 1 1 ) that detects the pressure of the grease within the grease cylinder 380; by comparing the data/reading obtained from the pressure sensor 436 with data/readings obtained from the pressure sensor 355, the controller 180 can determine whether the grease cylinder 380 is filled with grease after the piston 370 is stroked in the direction 415. As a result, the controller 180 can delay stroking the piston in the direction 410 until the grease cylinder 380 is completely filled with grease, thus improving the accuracy of greasing operations. In one or more embodiments, the controller 180 controls the metering modules 3202-N to deliver and meter grease to the process valves 31 02-N in substantially the same manner as that described above with respect to the metering module 320i and the process valves 310i ; therefore, the operation of the metering modules 3202-N to deliver and meter grease to the process valves 31 02-N will not be described in further detail. As a result, the controller 180 is capable of greasing the process valves 310I-N at any of the following intervals: timed intervals; continuous greasing (at a rate specified by the user or the database); greasing on command from an operator via a user interface (HMI) at any time; per operational stage (e.g., fracturing stage); per N stages; scheduled greasing; scheduled partial greasing; and/or any combination thereof.

[0101] In one or more embodiments, prior to delivering and metering grease to the process valves 31 0-I-N, the grease system 305 is capable of verifying that the process valves 31 0I-N are actuated to the proper position for greasing. To achieve such verification, the grease system 305 includes sensor(s) (e.g., the position sensors 205i and 225i shown in Figures 3 and 4) associated with the process valves 31 0I-N to ensure they are in the proper position prior to greasing. Such sensor(s) may include, for example, position sensor(s) and/or visual feedback devices (e.g., camera(s), image processing software, etc.) capable of detecting the position of the process valves 31 0-I-N. In addition, the grease system 305 may include actuator(s) adapted to receive control signals from the controller 180 to open or close the process valves 31 0I-N. AS a result, the controller 180 is able to automatically place the process valves 310I-N in the proper greasing position prior to greasing.

[0102] Referring to Figure 13, in one or more embodiments, a method of operating the grease system 305 is generally referred to by the reference numeral 440. The method 440 is carried out by receiving, at the controller 180, data/readings from the delivery module 315 (e.g., the pressure sensors 340 and 355) and/or the metering modules 320i- N (e.g., the cycle counter 420), and sending, from the controller 180, control signals to the delivery module 315 (e.g., the fluid transport devices 335 and 350, the return valve 360, or any combination thereof) and/or the metering modules 320I-N (e.g., the control valve 405, the lubricator valves 435I-N, or any combination thereof).

[0103] The method 440 includes at a step 445 delivering grease to a first one of the metering modules 320I-N. In one or more embodiments, the step 445 includes transporting the grease from the grease container 330 to the first one of the metering modules 320I-N. At a step 450, the controller 180 controls the actuator of the first one of the metering modules 320I-N SO that a first amount of the delivered grease is metered to a first one of the process valves 310I-N. In one or more embodiments, the step 450 includes: controlling the actuator of the first one of the metering modules 320I-N to start stroking the piston 370; determining how many strokes of the piston 370 are required to meter the first amount to the first one of the process valves 31 0I-N; and controlling the actuator to stop stroking the piston 370 when the strokes counted by the cycle counter 420 equal the determined number of strokes required. In one or more embodiments of the step 450, the controller 180 determines the first amount by retrieving data relating to the first one of the process valves 310I-N from a database.

[0104] At a step 455, grease is delivered to a second one of the metering modules 320i- N. In one or more embodiments, the step 455 includes transporting the grease from the grease container 330 to the second one of the metering modules 320I-N. At a step 260, the controller 180 controls the actuator of the second one of the metering modules 320i- N so that a second amount of the delivered grease is metered to a second one of the process valves 31 0-I-N. In one or more embodiments of the step 260, the controller 180 determines the second amount by retrieving data relating to the second one of the process valves 31 0I-N from a database.

[0105] In one or more embodiments, among other things, the operation of the grease system 305 and/or the execution of the method 440: ensures that an appropriate amount of grease is injected into each of the process valves 31 0I-N while monitoring the amount of grease injected into each of the process valves 31 0I-N; improves the flushing of debris and contaminants from the process valves 31 0I-N; improves the performance of the process valves 31 0I-N; decreases the risk that a less than adequate amount of grease is injected into the process valves 31 0-I-N; decreases the risk of malfunction and maintenance needs for the process valves 310-I-N; and/or reduces operators’ exposure to oil and gas process units during operation.

[0106] Referring to Figure 14, with continuing reference to Figures 1 -13, in one or more embodiments, a computing node 1000 for implementing one or more embodiments of one or more of the above-described elements, systems, apparatus, controllers, methods, and/or steps, or any combination thereof, is depicted. The node 1000 includes a microprocessor 1000a, an input device 1000b, a storage device 1000c, a video controller 1000d, a system memory 1000e, a display 10OOf, and a communication device 1000g all interconnected by one or more buses 1000h. In one or more embodiments, the microprocessor 1000a is, includes, or is part of, the controller 180 and/or the one or more other controllers described herein. In one or more embodiments, the storage device 1000c may include a floppy drive, hard drive, CD-ROM, optical drive, any other form of storage device or any combination thereof. In one or more embodiments, the storage device 1000c may include, and/or be capable of receiving, a floppy disk, CD-ROM, DVD-ROM, or any other form of computer-readable medium that may contain executable instructions. In one or more embodiments, the communication device 1000g may include a modem, network card, or any other device to enable the node 1000 to communicate with other nodes. In one or more embodiments, any node represents a plurality of interconnected (whether by intranet or Internet) computer systems, including without limitation, personal computers, mainframes, PDAs, smartphones and cell phones.

[0107] In one or more embodiments, one or more of the components of any of the above-described systems 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 above-described systems include respective pluralities of same components.

[0108] 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.

[0109] 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, personal digital assistants (PDAs), 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.

[0110] 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.

[0111] 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 one or more embodiments, 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.

[0112] 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 one or more embodiments of the present disclosure. In one or more embodiments, data structure may provide an organization of data, or an organization of executable code.

[0113] In one or more embodiments, any networks and/or one or more portions thereof, may be designed to work on any specific architecture. In one or more embodiments, 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.

[0114] In one or more embodiments, 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 one or more embodiments, 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 one or more embodiments, the database may exist remotely from the server, and run on a separate platform. In one or more embodiments, the database may be accessible across the Internet. In one or more embodiments, more than one database may be implemented. [0115] 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 the above-described operation of each of the above-described elements, systems, apparatus, controllers, methods, and/or steps, or any combination thereof. In one or more embodiments, such a processor may include one or more of the microprocessor 1000a, the controller 180, the one or more other controllers described herein, any processor(s) that are part of the components of the above-described systems, and/or any combination thereof, and such a computer readable medium may be distributed among one or more components of the above- described systems. 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 may 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.

[0116] A method has been disclosed. The method generally includes opening, or keeping open, a first valve, the first valve being part of a wellhead, the wellhead including a flow component above the first valve; wherein the method further includes: (i) detecting a state of the first valve, the state being open, partially-open, or closed; and in response to detecting the state of the first valve, metering an amount of grease to the first valve; and/or (ii) opening, or keeping open, a second valve, the second valve being operably coupled to the wellhead and positioned above the flow component; and after opening, or keeping open, each of the first and second valves: detecting whether the second valve is open or closed; in response to detecting that the second valve is open, preventing the first valve from being closed; and in response to detecting that the second valve is closed, allowing the first valve to be closed. In one or more embodiments, the method includes the steps recited in each of romanettes (i) and (ii). In one or more embodiments, the method includes the steps recited in romanette (i). In one or more embodiments, metering the amount of grease to the first valve includes: delivering grease from a delivery module to a metering module; and metering the amount of grease from the metering module to the first valve. In one or more embodiments, opening, or keeping open, the first valve includes opening the first valve; and wherein opening the first valve includes: determining if a difference between inlet and outlet pressures of the first valve is below a threshold; if said difference is not below the threshold, opening an equalization valve to decrease the difference until said difference is below the threshold; and if said difference is below the threshold, opening the first valve. In one or more embodiments, the method includes the steps recited in romanette (ii). In one or more embodiments, the method further includes: after opening, or keeping open, each of the first and second valves: closing the first valve; and opening a third valve, the third valve being operably coupled to the flow component of the wellhead. In one or more embodiments, the method further includes, after both closing the first valve and opening the third valve, pumping fracturing fluid into the wellbore through each of the third valve, the flow component, and the first valve, the flow component including a frac tree. In one or more embodiments, the method further includes, after opening, or keeping open, each of the first and second valves, deploying a downhole tool on a conveyance string through each of the first and second valves and into a wellbore operably associated with the wellhead; wherein the step of preventing the first valve from being closed in response to detecting that the second valve is open prevents the first valve from damaging the conveyance string when the downhole tool is deployed on the conveyance string through each of the first and second valves and into the wellbore. In one or more embodiments, the downhole tool includes a plug and perforating guns. In one or more embodiments, the method further includes, after deploying the downhole tool on the conveyance string through each of the first and second valves and into the wellbore, retrieving the conveyance string and at least a portion of the downhole tool from the wellbore and through each of the first and second valves; wherein the step of allowing the first valve to be closed in response to detecting that the second valve is closed allows the first valve to be closed after the at least a portion of the downhole tool is retrieved from the wellbore and through each of the first and second valves. In one or more embodiments, the method further includes, before opening, or keeping open, the first valve, attaching a lubricator in which the downhole tool extends to a latch operably coupled to the wellhead and positioned above the first valve; wherein deploying the downhole tool includes, after attaching the lubricator to the latch, deploying the downhole tool on the conveyance string from the lubricator, through the first and second valves, and into the wellbore. In one or more embodiments, the method further includes: after deploying the downhole tool on the conveyance string through each of the first and second valves and into the wellbore, retrieving the conveyance string and at least a portion of the downhole tool from the wellbore and through each of the first and second valves; and after retrieving the conveyance string and the at least a portion of the downhole tool from the wellbore and through each of the first and second valves: closing the second valve; and detaching the lubricator from the latch. In one or more embodiments, the method further includes, after detaching the lubricator from the latch, launching, from an object launcher operably associated with the wellhead and located above the first valve, an object through each of the first and second valves and into the wellbore.

[0117] An apparatus has also been disclosed. The 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: opening, or keeping open, a first valve, the first valve being part of a wellhead, the wellhead including a flow component above the first valve; wherein, when the instructions are executed by the one or more processors, the following steps are also executed: (i) detecting a state of the first valve, the state being open, partially-open, or closed; and in response to detecting the state of the first valve, metering an amount of grease to the first valve; and/or (ii) opening, or keeping open, a second valve, the second valve being operably coupled to the wellhead and positioned above the flow component; and after opening, or keeping open, each of the first and second valves: detecting whether the second valve is open or closed; in response to detecting that the second valve is open, preventing the first valve from being closed; and in response to detecting that the second valve is closed, allowing the first valve to be closed. In one or more embodiments, when the instructions are executed by the one or more processors, the steps recited in each of romanettes (i) and (ii) are executed. In one or more embodiments, when the instructions are executed by the one or more processors, the steps recited in romanette (i) are executed. In one or more embodiments, metering the amount of grease to the first valve includes: delivering grease from a delivery module to a metering module; and metering the amount of grease from the metering module to the first valve. In one or more embodiments, opening, or keeping open, the first valve includes opening the first valve; and opening the first valve includes: determining if a difference between inlet and outlet pressures of the first valve is below a threshold; if said difference is not below the threshold, opening an equalization valve to decrease the difference until said difference is below the threshold; and if said difference is below the threshold, opening the first valve. In one or more embodiments, when the instructions are executed by the one or more processors, the steps recited in romanette (ii) are executed. In one or more embodiments, when the instructions are executed by the one or more processors, the following steps are also executed: after opening, or keeping open, each of the first and second valves: closing the first valve; and opening a third valve, the third valve being operably coupled to the flow component of the wellhead. In one or more embodiments, when the instructions are executed by the one or more processors, the following step is also executed: before opening the third valve, launching, from an object launcher operably associated with the wellhead and located above the second valve, an object through each of the first and second valves and into the wellbore.

[0118] It is understood that variations may be made in the foregoing without departing from the scope of the present disclosure.

[0119] In one or more 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.

[0120] 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.

[0121] In one or more 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 one or more embodiments, the steps, processes, and/or procedures may be merged into one or more steps, processes and/or procedures.

[0122] In one or more 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.

[0123] 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. § 1 12(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.