DOWNHOLE FLOW COMMUNICATION-STIMULATING APPARATUSES, SYSTEMS, AND METHODS

Description

CROSS REFERENCE TO RELATED APPLICATION

This application claims priority from U.S. Provisional Application No. 63/686,128, filed Aug. 22, 2024, entitled DOWNHOLE FLOW COMMUNICATION-STIMULATING APPARATUSES, SYSTEMS, AND METHODS, the contents of which are incorporated by reference into the Detailed Description herein below in their entirety.

FIELD

The present disclosure relates to downhole tools for readying wellbores for production.

BACKGROUND

Darts are often deployed downhole within wellbores to actuate downhole operations. Intelligent darts can prematurely actuate and become seated in an undesirable location, and thereby result in unnecessary operational costs and, potentially, abandonment of a well.

SUMMARY

In one aspect, there is provided a wellbore material transfer system for conducting fluid between the surface and a subterranean formation via a wellbore, comprising:

• • a wellbore string disposed within the wellbore and defining a wellbore string passage, wherein the wellbore string includes a series of “N” downhole tool apparatuses, each one of the downhole tool apparatuses, independently, including a downhole tool, and one or more downhole one(s) of the “N” downhole tool apparatuses, that is(are) disposed downhole relative to the furthest uphole one of the “N” downhole tool apparatuses, define a series of “N−1” downhole one(s) of the “N” downhole tool apparatuses, and for each one of the “N−1” downhole one(s) of the “N” downhole tool apparatuses, independently, a respective series of one or more uphole one(s) of the “N” downhole tool apparatuses is(are) disposed uphole relative to the downhole one of the “N” downhole tool apparatuses, such that for the downhole one of the “N” downhole tool apparatuses, the one or more uphole-disposed downhole tool apparatus(es), that is (are) respective to the downhole one of the “N” downhole tool apparatuses, is a total number of (i−1) uphole-disposed downhole tool apparatus(es) that is(are) respective to the downhole one of the “N” downhole tool apparatuses;
  • for each one of the “N−1” downhole one(s) of the “N” downhole tool apparatuses, independently, a respective dart, configurable in an activation-disabled configuration, that is respective to the dart that is respective to the downhole one of the “N” downhole tool apparatuses, an activation-enabled, coupling-ineffective configuration, that is respective to the dart that is respective to the downhole one of the “N” downhole tool apparatuses, and a coupling-effective configuration, that is respective to the dart that is respective to the downhole one of the “N” downhole tool apparatuses;
  • an activation tool configured for generating an activation tool field within an activation zone;
  • for each one of the “N−1” downhole one(s) of the “N” downhole tool apparatuses, independently, a respective proximity triggering configuration that is configured for generating a field for activating the transitioning of the dart, that is respective to the downhole one of the “N” downhole tool apparatuses, from the activation-enabled, coupling-ineffective configuration, that is respective to the dart that is respective to the downhole one of the “N” downhole tool apparatuses, to the coupling-effective configuration, that is respective to the dart that is respective to the downhole one of the “N” downhole tool apparatuses;
    wherein:
  • for each one of the “N−1” downhole one(s) of the “N” downhole tool apparatuses, independently, the dart, that is respective to the downhole one of the “N” downhole tool apparatuses, and the activation tool are co-operatively configured such that:
    • while the activation tool is generating a field within the activation zone, and while the dart, that is respective to the downhole one of the “N” downhole tool apparatuses, is disposed in the activation-disabled configuration and being conveyed within the activation zone, transitioning of the dart, that is respective to the downhole one of the “N” downhole tool apparatuses, from the activation-disabled configuration, that is respective to the dart that is respective to the downhole one of the “N” downhole tool apparatuses, to the activation-enabled, coupling-ineffective configuration, that is respective to the dart that is respective to the downhole one of the “N” downhole tool apparatuses, is effectuated by the activation tool field that is generated by the activation tool;
  • and
  • for each one of the “N−1” downhole one(s) of the “N” downhole tool apparatuses, independently, the downhole one of the “N” downhole tool apparatuses, the dart, that is respective to the downhole one of the “N” downhole tool apparatuses, and the one or more uphole-disposed downhole tool apparatus(es) that is(are) respective to the downhole one of the “N” downhole tool apparatuses, are co-operatively configured such that:
    • while the dart, that is respective to the downhole one of the “N” downhole tool apparatuses, is disposed in the activation-enabled, coupling-ineffective configuration, that is respective to the dart that is respective to the downhole one of the “N” downhole tool apparatuses, and being conveyed, via the passage of the wellbore string, to the downhole one of the “N” downhole tool apparatuses, such that the dart, that is respective to the downhole one of the “N” downhole tool apparatuses, is traversing the one or more uphole-disposed downhole tool apparatus(es), that is(are) respective to the downhole one of the “N” downhole tool apparatuses, for each one of the one or more uphole-disposed downhole tool apparatuses, that is(are) respective to the downhole one of the “N” downhole tool apparatuses, independently, the dart, that is respective to the downhole one of the “N” downhole tool apparatuses, traverses the uphole-disposed downhole tool apparatus that is respective to the downhole one of the “N” downhole tool apparatuses, such that there is an absence of coupling of the dart, that is respective to the downhole one of the “N” downhole tool apparatuses, to the downhole tool that is respective to the uphole-disposed downhole tool apparatus that is respective to the downhole one of the “N” downhole tool apparatuses, and such that the dart, that is respective to the downhole one of the “N” downhole tool apparatuses, becomes disposed downhole relative to the one or more uphole-disposed downhole tool apparatuses that is (are) respective to the downhole one of the “N” downhole tool apparatuses; and
    • while the dart, that is respective to the downhole one of the “N” downhole tool apparatuses, is disposed in the activation-enabled, coupling-ineffective configuration that is respective to the dart that is respective to the downhole one of the “N” downhole tool apparatuses, and being conveyed through the wellbore string passage and becomes disposed within sufficient proximity of the proximity triggering configuration that is respective to the downhole one of the “N” downhole tool apparatuses, the transitioning of the dart, that is respective to the downhole one of the “N” downhole tool apparatuses, from the activation-enabled, coupling-ineffective configuration, that is respective to the dart that is respective to the downhole one of the “N” downhole tool apparatuses, to the coupling-effective configuration, that is respective to the dart that is respective to the downhole one of the “N” downhole tool apparatuses, is effectuated by the field that is generated by the proximity triggering configuration that is respective to the downhole one of the “N” downhole tool apparatuses, such that the dart, that is respective to the downhole one of the “N” downhole tool apparatuses, becomes effective for coupling to the downhole tool that is respective to the downhole one of the “N” downhole tool apparatuses for actuating a downhole operation by the downhole tool that is respective to the downhole one of the “N” downhole tool apparatuses.

In another aspect, there is provided a wellbore material transfer system for conducting fluid between the surface and a subterranean formation via a wellbore, comprising:

• • a dart configurable in a coupling-ineffective configuration and a coupling-effective configuration; and
  • a wellbore completion including:
    • a downhole tool apparatus including a downhole tool and an activator for urging transitioning of the dart from the coupling-ineffective configuration to the coupling-effective configuration;
  • and
    • a landing tool apparatus, disposed uphole relative to the downhole tool apparatus;
  • wherein:
    • the dart and the wellbore completion are co-operatively configured such that while the dart is disposed in the coupling-ineffective configuration and being motivated to traverse the wellbore completion:
      • the dart traverses the landing tool apparatus such that the dart becomes disposed downhole relative to the landing tool apparatus; and
      • after having traversed the landing tool apparatus, and while the dart is traversing the downhole tool apparatus:
        • the dart is activated by the activator, with effect that the dart transitions from the coupling-ineffective configuration to the coupling-effective configuration;
        • after having transitioned to the coupling-effective configuration, the dart becomes coupled to the downhole tool, such that an actuation-ready downhole tool is established; and
        • after the actuation-ready downhole tool is established, a downhole operation, by the downhole tool, is effectuated;
    • and
    • the dart and the wellbore completion are co-operatively configured such that while the dart is disposed in the coupling-effective configuration and being motivated to traverse the downhole completion:
  • the dart becomes coupled to the landing tool apparatus, with effect that the dart is prevented from being displaced relative to the landing tool apparatus such that a landed dart configuration is obtained.

In another aspect, there is provided a wellbore material transfer system for conducting fluid between the surface and a subterranean formation via a wellbore, comprising:

• • a wellbore string disposed within the wellbore and defining a wellbore string passage, wherein the wellbore string includes a plurality of downhole tool apparatuses, wherein the plurality of downhole tool apparatuses is a series of “N” downhole tool apparatuses, only, wherein the series of “N” downhole tool apparatuses defines a furthest uphole one of the downhole tool apparatuses, and each one of the downhole tool apparatuses, independently, including a downhole tool;
  • for each one of the “N” downhole tool apparatuses, independently, a respective dart, configurable in a coupling-ineffective configuration, that is respective to the dart that is respective to the downhole tool apparatus, and a coupling-effective configuration, that is respective to the dart that is respective to the downhole tool apparatus; and
  • for each one of the “N” downhole tool apparatuses, independently, a respective proximity triggering configuration that is configured for generating a respective field, within a respective activation zone, for activating the transitioning of the dart, that is respective to the downhole tool apparatus, from the coupling-ineffective configuration, that is respective to the dart that is respective to the downhole tool apparatus, to the coupling-effective configuration, that is respective to the dart that is respective to the downhole tool apparatus;
  • wherein, for each one of the “N” downhole tool apparatuses, independently:
    • in the coupling-ineffective configuration, that is respective to the dart that is respective to the downhole tool apparatus:
      • the dart, that is respective to the downhole tool apparatus, and the downhole tool apparatus are co-operatively configured such that the dart, that is respective to the downhole tool apparatus, is:
      • (i) ineffective for coupling to the downhole tool that is respective to the downhole tool apparatus, to which the dart is respective; and
      • (ii) co-operable with the proximity triggering configuration, that is respective to the downhole tool apparatus, such that, while the dart, that is respective to the downhole tool apparatus, is disposed within a field, that is respective to the downhole tool apparatus, and is disposed within the activation zone that is respective to the downhole tool apparatus, and being generated by the proximity triggering configuration that is respective to the downhole tool apparatus, transitioning of the dart, that is respective to the downhole tool apparatus, to the coupling-effective configuration, that is respective to the dart that is respective the downhole tool apparatus, is effectuated;
    • and
    • in the coupling-effective configuration, that is respective to the dart that is respective to the downhole tool apparatus:
  • the dart, that is respective to the downhole tool apparatus, and the downhole tool apparatus are co-operatively configured such that the dart, that is respective to the downhole tool apparatus, is effective for coupling to the downhole tool that is respective to the downhole tool apparatus, to which the dart is respective, motivating a downhole operation by the downhole tool that is respective to the downhole tool

BRIEF DESCRIPTION OF DRAWINGS

The preferred embodiments will now be described with the following accompanying drawings, in which:

FIGS. 1 to 7 are schematic illustrations depicting implementation of an embodiment of a method for stimulating production of fluidic hydrocarbon-comprising material from a subterranean formation and, after the stimulation, producing fluidic hydrocarbon-comprising material from the subterranean formation, via an embodiment of the system of the present disclosure; and

FIG. 8 is a schematic illustration of a system for stimulating production of fluidic hydrocarbon-comprising material from a subterranean formation and, after the stimulation, producing fluidic hydrocarbon-comprising material from the subterranean formation, with an activation tool configuration;

FIG. 9 is a schematic illustration of a system for stimulating production of fluidic hydrocarbon-comprising material from a subterranean formation and, after the stimulation, producing fluidic hydrocarbon-comprising material from the subterranean formation, with a landing tool apparatus;

FIG. 10 is a schematic illustration of a system for stimulating production of fluidic hydrocarbon-comprising material from a subterranean formation and, after the stimulation, producing fluidic hydrocarbon-comprising material from the subterranean formation, with a dart activation apparatus; and

FIG. 11 is a schematic illustration of another embodiment of the dart activation apparatus.

DETAILED DESCRIPTION

The present disclosure provides apparatuses and systems that can be used in well completion for enabling selective flow communication between a wellbore 102 and a subterranean formation 100.

Referring to FIGS. 1 to 7, there is provided a wellbore material transfer system 5 for conducting (e.g. flowing) material from the surface 10 to a subterranean formation 100 via a wellbore 102. In some embodiments, for example, the subterranean formation 100 is a hydrocarbon material-containing reservoir.

The wellbore 102 can be straight, curved, or branched. The wellbore 102 can have various wellbore sections. A wellbore section is an axial length of a wellbore 102. A wellbore section can be characterized as “vertical” or “horizontal” even though the actual axial orientation can vary from true vertical or true horizontal, and even though the axial path can tend to “corkscrew” or otherwise vary. The term “horizontal”, when used to describe a wellbore section, refers to a horizontal or highly deviated wellbore section as understood in the art, such as, for example, a wellbore section having a longitudinal axis that is between 70 and 110 degrees from vertical.

In some embodiments, for example, the conducting includes conducting of fluid flow for enabling the downhole deployment of tools. In some embodiments, for example, the conducting includes conducting of treatment material from the surface 10 to the subterranean formation 100 for stimulating the subterranean formation 100 for production of the reservoir fluid.

In some embodiments, for example, the conducting (such as, for example, by flowing) treatment material to the subterranean formation 100 via the wellbore 102 is for effecting selective stimulation of the subterranean formation 100, such as a subterranean formation 100 including a hydrocarbon material-containing reservoir. The stimulation is effected by supplying the treatment material to the subterranean formation 100. In some embodiments, for example, the treatment material includes a liquid, such as a liquid including water. In some embodiments, for example, the liquid includes water and chemical additives. In other embodiments, for example, the stimulation material is a slurry including water and solid particulate matter, such as proppant. In some embodiments, for example the treatment material includes chemical additives. Exemplary chemical additives include acids, sodium chloride, polyacrylamide, ethylene glycol, borate salts, sodium and potassium carbonates, glutaraldehyde, guar gum and other water soluble gels, citric acid, and isopropanol. In some embodiments, for example, the treatment material is supplied to effect hydraulic fracturing of the reservoir.

In some embodiments, for example, the conducting of fluid, to and from the wellhead, is effected via a wellbore string 104. The wellbore string 104 may include pipe, casing 105, or liner, and may also include various forms of tubular segments. The wellbore string 104 defines a wellbore string passage 106 for effecting conduction of fluids between the surface 10 and the subterranean formation 100.

In some embodiments, for example, the wellbore 102 includes a cased-hole completion, in which case, the wellbore string 104 includes a casing 105.

A cased-hole completion involves running casing 105 down into the wellbore 102 through the production zone. The casing 105 at least contributes to the stabilization of the subterranean formation 100 after the wellbore 102 has been completed, by at least contributing to the prevention of the collapse of the subterranean formation 100 that is defining the wellbore 102. In some embodiments, for example, the casing 105 includes one or more successively deployed concentric casing 105 strings, each one of which is positioned within the wellbore 102, having one end extending from the well head. In this respect, the casing strings 105 are typically run back up to the surface. In some embodiments, for example, each casing string 105 includes a plurality of jointed segments of pipe. The jointed segments of pipe typically have threaded connections. In some embodiments, for example, such as for deep wells, it becomes challenging to suspend casing strings from the surface and, as such, in such embodiments, a liner string is typically run in and suspended from a casing string.

In some embodiments, for example, the annular region between the wellbore string 104 and the subterranean formation 100 (and, in some embodiments, for example, between the liner and the subterranean formation) is filled with cement for effecting zonal isolation. The cement is disposed between the wellbore string 104 and the subterranean formation 100 for the purpose of effecting isolation of one or more zones of the subterranean formation from fluids disposed in another zone of the subterranean formation. Such fluids include formation fluid being produced from another zone of the subterranean formation 100 (in some embodiments, for example, such formation fluid being flowed through a production string disposed within and extending through the wellbore string 104 to the surface), or injected stimulation material. In some embodiments, for example, the cement also provides one or more of the following functions: (a) strengthens and reinforces the structural integrity of the wellbore, (b) prevents produced formation fluids of one zone from being diluted by water from other zones. (c) mitigates corrosion of the wellbore string 104, and (d) at least contributes to the support of the wellbore string 104. The zonal isolation material is introduced to an annular region between the wellbore string 104 and the subterranean formation 100 after the subject wellbore string 104 has been run into the wellbore 102. In some embodiments, for example, the zonal isolation material includes cement.

In some embodiments, for example, the wellbore string 104 includes a plurality of downhole tool stations. Successive downhole tool stations 110, 112, 114 may be axially spaced from each other along the wellbore 102. In some embodiments, for example, the spacing is such that each one of the downhole tool stations 110, 112, 114, independently, is positioned adjacent a respective zone (or interval) 100A, 100B, 100C of the subterranean formation 100. In some embodiments, for example, the plurality of downhole tool stations 110, 112, 114 is defined by a series of downhole tool stations that are spaced along a longitudinal axis of the wellbore 102.

In some embodiments, for example, the plurality of downhole tool stations 110, 112, 114, is defined by a plurality of flow communication stations that are emplaced within the wellbore string 104 at the interface between the subterranean formation 100 and the wellbore 102. Each one of the flow communication stations, independently, effects flow communication between the wellbore 102 and a respective zone (or interval) of the subterranean formation 100.

In those embodiments where the plurality of downhole tool stations 110, 112, 114 is defined by a plurality of flow communication stations, in some of these embodiments, for example, the conducting of fluid flow between the surface 10 and the subterranean formation 100, via the plurality of flow communication stations, is effected through the passage 106 of the wellbore string 104.

In those embodiments where the plurality of downhole tool stations 110, 112, 114 is defined by a plurality of flow communication stations, in some of these embodiments, for example, the fluid being conducted is conducted downhole, from the surface 10 and to the subterranean formation 100. In those embodiments where the fluid is being conducted downhole, in some of these embodiments, for example, the conducted fluid includes fluid that is urging deployment of downhole tools (e.g. darts, tools that are mounted to coiled tubing). In some of these embodiments, for example, the conducted fluid includes treatment material, such that the fluid being conducted is for stimulating production of hydrocarbons from the subterranean formation 100.

In those embodiments where the plurality of downhole tool stations 110, 112, 114 is defined by a plurality of flow communication stations, in some of these embodiments, for example, the fluid being conducted is conducted uphole, from the subterranean formation 100 to the surface 10. In this respect, in some of these embodiments, for example, the conducted fluid includes produced hydrocarbons.

In those embodiments where fluid is being conducted downhole from the surface 10 to the subterranean formation 100 via the plurality of flow communication stations, in some of these embodiments, for example, to effect flow communication between the surface 10 and the subterranean formation for enabling the conducting of the fluid from the surface 10 to the subterranean formation 100, one or more of the flow communication stations 110, 112, 114 are configured for at least injecting the fluid into the subterranean formation.

Each one of the one or more downhole tool stations 110, 112, 114 includes one or more respective downhole tool apparatuses 200, such that a plurality of downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C) is defined. In some embodiments, for example, the plurality of downhole tool apparatuses is a total number of “N” downhole tool apparatuses in series, wherein “N” is a whole number that is greater than one (1). In this respect, the wellbore string 104 includes a series of “N” downhole tool apparatuses. In some embodiments, for example, the wellbore string 104 includes a plurality of downhole tool apparatuses, and the plurality of downhole tool apparatuses is a series of “N” downhole tool apparatuses, only. In some embodiments, for example, for each one of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, includes a respective downhole tool apparatus housing 212 that is integrated within the wellbore string 104 and also includes a respective downhole tool 214. In some embodiments, for example, for each one of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, the integration is effected, for example, by way of welding. In some embodiments, for example, for each one of the apparatuses 200, independently, the integration is by threaded coupling at the uphole and downhole ends of the apparatus, and, in this respect, in some embodiments, for example, for each one of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, each one of the uphole and downhole ends of the downhole tool apparatus housing 201, independently, is configured for such threaded coupling to other portions of the wellbore string 104. In some embodiments, for example, each one of the downhole tool apparatuses 200, independently, is a wellbore sub.

In some embodiments, for example, each one of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, is configured for transitioning from a respective first state to a respective second state, in response to application of a force (e.g. a force that is, or is derived from, a fluid pressure force applied by fluid within the passage 106 of the wellbore string 104, such as that established by a fluid pressure differential within the passage 106 of the wellbore string 104). In some of these embodiments, for example, the application of a force is an application of a force in the downhole direction. In some embodiments, for example, each one of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, the transitioning is with effect that a downhole operation is performed by the downhole tool 214 that is respective to the downhole tool apparatus.

In some embodiments, for example, for each one of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, the first state, that is respective to the downhole tool apparatus, includes a respective transition-ineffective state and a respective transition-effective state, such that each one of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, is configurable in a respective transition-ineffective first state, a respective transition-effective first state, and a respective second state. In this respect, each one of the “N” downhole tool apparatuses (200A, 200B, 200C), is configured for transitioning from the transition-ineffective first state, that is respective to the downhole tool apparatus, to the transition-effective first state, that is respective to the downhole tool apparatus, and is also configured for transitioning from the transition-effective first state, that is respective to the downhole tool apparatus, to the second state, that is respective to the downhole tool apparatus. In those embodiments where, for each one of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), the first state, that is respective to the downhole tool apparatus, includes a transition-ineffective state, that is respective to the downhole tool apparatus, and a transition-effective state, that is respective to the downhole tool apparatus, in some of these embodiments, for example, the transitioning of the downhole tool 214, that is respective to the downhole tool apparatus, from the first state, that is respective to the downhole tool apparatus, to the second state, that is respective to the downhole tool apparatus, is a transitioning from the transition-effective first state, that is respective to the downhole tool apparatus, to the second state, that is respective to the downhole tool apparatus, such that the transitioning from the transition-effective first state, that is respective to the downhole tool apparatus, to the second state, that is respective to the downhole tool apparatus, is with effect that a downhole operation is performed by the downhole tool 214 that is respective to the downhole tool apparatus. In some embodiments, for example, for each one of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently: in the transition-ineffective first state that is respective to the downhole tool apparatus, the downhole tool 214, that is respective to the downhole tool apparatus, is disabled such that the downhole tool 214, that is respective to the downhole tool apparatus, is prevented from performing a downhole operation, and, in the transition-effective state, that is respective to the downhole tool apparatus, the downhole tool 214, that is respective to the downhole tool apparatus, is enabled such that there is an absence of prevention of the performance of a downhole operation by the downhole tool that is respective to the downhole tool apparatus. For each one of the “N” downhole tool apparatuses, independently, the transitioning of the downhole tool apparatus, from the transition-ineffective first state, that is respective to the downhole tool apparatus, to the transition-effective first state, that is respective to the downhole tool apparatus, is motivated by a defeating of the disablement of the downhole tool 214 that is respective to the downhole tool apparatus, and the defeating of the disablement is motivated by an application of a force (e.g. a force that is, or is derived from, a fluid pressure force applied by fluid within the passage 106 of the wellbore string 104, such as that established by a fluid pressure differential within the passage 106 of the wellbore string 104) to the downhole tool 214, that is respective to the downhole tool apparatus, and, in some of these embodiments, for example, the applied force is a force that exceeds a first minimum predetermined value only, and, in some of these embodiments, for example, the applied force is a force directed in the downhole direction. For each one of the “N” downhole tool apparatus, independently, the transitioning of the downhole tool apparatus, from the transition-effective first state, that is respective to the downhole tool apparatus, to the second state, that is respective to the downhole tool apparatus, is established in response to an application of a force (e.g. a force that is, or is derived from, a fluid pressure force applied by fluid within the passage 106 of the wellbore string 104, such as that established by a fluid pressure differential within the passage 106 of the wellbore string 104), to the downhole tool 214 that is respective to the downhole tool apparatus, and, in some of these embodiments, for example, the applied force is a force that exceeds a second minimum predetermined value only, and, in some of these embodiments, for example, the applied force is a force directed in the downhole direction. The first minimum predetermined value is greater than the second minimum predetermined value. In some embodiments, for example, the first minimum predetermined value is greater than the second minimum predetermined value by a multiple of at least 1.5, such as, for example, at least two (2), such as, for example, at least three (3). In some embodiments, for example, for each one of the “N” downhole tool apparatuses, independently, the transitioning of the downhole tool apparatus, from the transition-ineffective first state, that is respective to the downhole tool apparatus, to the transition-effective first state, that is respective to the downhole tool apparatus, and the transitioning of the downhole tool apparatus, from the transition-effective first state, that is respective to the downhole tool apparatus, to the second state, that is respective to the downhole tool apparatus, is motivated by a continued application of a force (e.g. a force that is, or is derived from, a fluid pressure force applied by fluid within the passage 106 of the wellbore string 104, such as that established by a fluid pressure differential within the passage 106 of the wellbore string 104), to the downhole tool 214 that is respective to the downhole tool apparatus.

In some embodiments, for example, the plurality of downhole tool stations (e.g. 110, 112, 114) is a plurality of flow communication stations, and, for each one of the downhole tool stations, independently, the downhole tool apparatus, that is respective to the downhole tool station, is a flow control apparatus, such that a plurality of flow control apparatuses (e.g. apparatuses 200A, 200B, 200C) is established, and each one of the flow control apparatuses, independently, includes a respective flow communicator 208 (e.g. such as, for example, one or more ports) and a respective valve 210 (such as, for example, a sliding sleeve) and the flow communicator 208, that is respective to the flow control apparatus, co-operates with the valve 210, that is respective to the flow control apparatus, to define a flow control configuration that is respective to the flow control apparatus, such that the downhole tool, that is respective to the downhole tool apparatus, includes the flow control configuration that is respective to the flow control apparatus. For each one of the “N” flow control apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, the flow control configuration is configurable in a respective closed configuration and in a respective open configuration. For each one of the “N” flow control apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, in the closed configuration, that is respective to the flow control configuration that is respective to the flow control apparatus, there is an absence of flow communication between the subterranean formation 100 and the wellbore string passage 106 via the flow communicator 208 that is respective to the flow control apparatus. For each one of the “N” flow control apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, in the open configuration, that is respective to the flow control configuration that is respective to the flow control apparatus, flow communication is established between the subterranean formation 100 and the wellbore string passage 106 via the flow communicator 208 that is respective to the flow control apparatus. In some embodiments, for example, for each one of the “N” flow control apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, the flow control configuration, that is respective to the flow control apparatus, is configured such that transitioning from the closed configuration, that is respective to the flow control configuration that is respective to the flow control apparatus, to the open configuration, that is respective to the flow control configuration that is respective to the flow control apparatus, is motivated by a displacement of the valve 210, that is respective to the flow control apparatus, relative to the flow communicator 208, that is respective to the flow control apparatus, and, in some of these embodiments, for example, the displacement is motivated by an application of a force (e.g. a force that is, or is derived from, a fluid pressure force applied by fluid within the passage 106 of the wellbore string 104, such as that established by a fluid pressure differential within the passage 106 of the wellbore string 104) to the valve 210 that is respective to the flow control apparatus, and, in some embodiments, for example, the application of a force is in the downhole direction. In this respect, in some embodiments, for example, for each one of the “N” flow control apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, the valve 210, that is respective to the flow control apparatus, is displaceable (in response to an application of a force (e.g. a force that is, or is derived from, a fluid pressure force applied by fluid within the passage 106 of the wellbore string 104, such as that established by a fluid pressure differential within the passage 106 of the wellbore string 104) to the valve 210 that is respective to the flow control apparatus, and, in some embodiments, for example, the application of a force is in the downhole direction) relative to the flow communicator 208, that is respective to the flow control apparatus, for establishing flow communication, via the flow communicator 208, that is respective to the flow control apparatus, between the subterranean formation 100 and the wellbore string passage 106. In this respect, for each one of the “N” flow control apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, the valve 210, that is respective to the flow control apparatus, is displaceable (in response to an application of a force (e.g. a force that is, or is derived from, a fluid pressure force applied by fluid within the passage 106 of the wellbore string 104, such as that established by a fluid pressure differential within the passage 106 of the wellbore string 104) to the valve 210 that is respective to the flow control apparatus, and, in some embodiments, for example, the application of a force is in the downhole direction) relative to the flow communicator 208, that is respective to the flow control apparatus, for motivating an opening of the flow communicator 208 that is respective to the flow control apparatus.

In those embodiments where, for each one of the downhole tool stations (e.g. 110, 112, 114), independently, the downhole tool apparatus, that is respective to the downhole tool station, is transitionable from the first state, that is respective to the downhole tool apparatus, to the second state that is respective to the downhole tool apparatus, and the plurality of downhole tool stations (e.g. 110, 112, 114) is a plurality of flow communication stations, and, for each one of the downhole tool stations, independently, the downhole tool apparatus, that is respective to the downhole tool station, is a flow control apparatus, in some of these embodiments, for example, for each one of the downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, as a corollary to the transitioning of the downhole tool apparatus, from the first state, that is respective to the downhole tool apparatus, to the second state, that is respective to the downhole tool apparatus, there is a transitioning of the flow control configuration, that is respective to the flow control apparatus, from the closed configuration, that is respective to the flow control configuration that is respective to the flow control apparatus, to the open configuration that is respective to the flow control configuration that is respective to the flow control apparatus.

Also in those embodiments where, for each one of the downhole tool stations 110, 112, 114, independently, the respective downhole tool apparatus is transitionable from the transition-ineffective first state to the transition-effective first state, and is also transitionable from the transition-effective first state to the second state, and the plurality of downhole tool stations (e.g. 110, 112, 114) is a plurality of flow communication stations, and, for each one of the downhole tool stations, independently, the downhole tool apparatus, that is respective to the downhole tool station, is a flow control apparatus, in some of these embodiments, for example, for each one of the downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently:

• • in the transition-ineffective first state,
    • (i) the flow control configuration, that is respective to the flow control apparatus that is respective to the downhole tool station, is configured in the closed configuration that is respective to the flow control configuration that is respective to the flow control apparatus that is respective to the downhole tool station, and
    • (ii) the valve 210, that is respective to the flow control apparatus that is respective to the flow communication station, is retained to the wellbore string 110 by a frangible connection (e.g. by one or more shear pins), such that, the transitioning from the closed configuration, that is respective to the flow control configuration that is respective to the flow control apparatus, to the open configuration, that is respective to the flow control configuration that is respective to the flow control apparatus, is prevented, and, as a corollary, the transitioning from the transition-ineffective first state, that is respective to the flow control apparatus, to the transition-effective first state, that is respective to the flow control apparatus, is prevented, such that the prevention of the performance of a downhole operation by the downhole tool, that is respective to the downhole tool apparatus, is the prevention of the transitioning from the closed configuration, that is respective to the flow control configuration that is respective to the flow control apparatus, to the open configuration, that is respective to the flow control configuration that is respective to the flow control apparatus;
  • and such that the transition-ineffective first state is a transition-ineffective closed configuration;
  • and in the transition-effective first state:
    • (i) the flow control configuration, that is respective to the flow control apparatus that is respective to the downhole tool station, is configured in the closed configuration that is respective to the flow control configuration that is respective to the flow control apparatus that is respective to the downhole tool station, and
    • (ii) there is an absence of retention of the valve 210, that is respective to the flow control apparatus that is respective to the flow communication station, to the wellbore string, such that the valve 210 is released for the transitioning from the closed configuration, that is respective to the flow control configuration that is respective to the flow control apparatus, to the open configuration, that is respective to the flow control configuration that is respective to the flow control apparatus, and, as a corollary, for the transitioning from the transition-effective first state, that is respective to the flow control apparatus, to the second state, that is respective to the flow control apparatus, such that the absence of prevention of the performance of a downhole operation by the downhole tool, that is respective to the downhole tool apparatus, is the absence of retention of the valve 210, that is respective to the flow control apparatus that is respective to the flow communication station, to the wellbore string,
  • and such that the transition-effective first state is a transition-effective closed configuration;
  • and in the second state:
    • the flow control configuration, that is respective to the flow control apparatus that is respective to the downhole tool station, is configured in the closed configuration that is respective to the flow control configuration that is respective to the flow control apparatus that is respective to the downhole tool station,
  • and the transitioning of the flow control apparatus, that is respective to the flow communication station, from the transition-ineffective first state, that is respective to the flow control apparatus, to the transition-effective first state, that is respective to the flow control apparatus, is motivated by a defeating of the retention by the frangible connection (e.g. shearing of the one or more shear pins), that is respective to the flow control apparatus, such that the defeating of the disablement of the downhole tool 214, that is respective to the downhole tool apparatus, is the defeating of the retention by the frangible connection that is respective to the flow control apparatus;
  • and the transitioning of the flow control apparatus, that is respective to the flow communication station, from the transition-effective first state, that is respective to the flow control apparatus, to the second state, that is respective to the flow control apparatus, is motivated by the displacement of the valve 210, that is respective to the flow control apparatus that is respective to the flow communication station, relative to the flow communicator 208, that is respective to the flow control apparatus that is respective to the flow communication station, such that the performance of a downhole operation, by the downhole tool 214, that is respective to the downhole tool apparatus, is the displacement of the valve 210, that is respective to the flow control apparatus that is respective to the flow communication station, relative to the flow communicator 208.

In some embodiments, for example, for each one of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, a respective dart 300 is configured for becoming co-operatively emplaced relative to the downhole tool that is respective to the downhole tool apparatus. In some of these embodiments, for example, for each one of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, the co-operative emplacement of the dart 300, that is respective to the downhole tool apparatus, relative to the downhole tool, that is respective to the downhole tool apparatus, includes a coupling of the dart 300, that is respective to the downhole tool apparatus, to the downhole tool, such that a coupled dart configuration is obtained, and such that the coupling of the dart 300, that is respective to the downhole tool apparatus, to the downhole tool that is respective to the downhole tool apparatus is effectuated. In those embodiments where each one of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, is configured for the transitioning from the first state, that is respective to the flow control apparatus, to the second state, that is respective to the flow control apparatus, in some of these embodiments, for example, the co-operative emplacement of the dart 300, that is respective to the downhole tool apparatus, relative to the downhole tool, that is respective to the downhole tool apparatus, is for the transmitting of a force (e.g. a force that is, or is derived from, a fluid pressure force applied by fluid within the passage 106 of the wellbore string 104, such as that established by a fluid pressure differential within the passage 106 of the wellbore string 104) that is applied to the dart (e.g. in a downhole direction), that is respective to the downhole tool apparatus, for the motivating of the transitioning from the first state, that is respective to the flow control apparatus, to the second state, that is respective to the flow control apparatus, with effect that the downhole operation is performed by the downhole tool 214 that is respective to the downhole tool apparatus. In those embodiments where each one of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, is configured for transitioning from the transition-ineffective first state, that is respective to the downhole tool apparatus, to the transition-effective first state, that is respective to the downhole tool apparatus, and also configured for transitioning from the transition-effective first state, that is respective to the downhole tool apparatus, to the second state, that is respective to the downhole tool apparatus, in some of these embodiments, for example, the co-operative emplacement of the dart 300, that is respective to the downhole tool apparatus, relative to the downhole tool, that is respective to the downhole tool apparatus, is for the transmitting of a force (e.g. a force that is, or is derived from, a fluid pressure force applied by fluid within the passage 106 of the wellbore string 104, such as that established by a fluid pressure differential within the passage 106 of the wellbore string 104) that is applied to the dart 300, that is respective to the downhole tool apparatus, for the motivating of the transitioning from the transition-ineffective first state, that is respective to the downhole tool apparatus, to the transition-effective first state, that is respective to the downhole tool apparatus, and also for the transmitting of a force (e.g. a force that is, or is derived from, a fluid pressure force applied by fluid within the passage 106 of the wellbore string 104, such as that established by a fluid pressure differential within the passage 106 of the wellbore string 104) that is applied to the dart 300, that is respective to the downhole tool apparatus, for the motivating of the transitioning from the transition-effective first state, that is respective to the downhole tool apparatus, to the second state, that is respective to the downhole tool apparatus, with effect that the downhole operation is performed by the downhole tool 214 that is respective to the downhole tool apparatus.

In some embodiments, for example, the dart 300 is a plug or a ball. In some embodiments, for example, the dart 300 is untethered. In the context of this disclosure, an “untethered dart” refers to a dart that is deployed downhole along a path through the wellbore and, for at least a portion of the path, the deployment is effected in the absence of motivation by a conveyance mechanism, such as, for example, slickline, wireline, or coiled tubing. In some embodiments, for example, the deployment is a displacement from the surface 10 and into the wellbore string passage 106, such as, for example, a displacement motivated by frictional forces applied by flowing fluid that is injected into the wellbore string 104 from the surface and discharged into the subterranean formation via a toe valve 116, such as, for example, a displacement motivated by pumping down of the dart 300.

In some embodiments, for example, each one of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, includes a respective downhole seat 216 for receiving seating of the dart 300 that is respective to the downhole tool apparatus, and, for each one of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, the downhole seat 216, that is respective to the downhole tool apparatus, is co-operable with the dart 300, that is respective to the downhole tool apparatus, such that, while the dart 300, that is respective to the downhole tool apparatus, is seated on the downhole seat 216, that is respective to the downhole tool apparatus, the seated dart configuration, that is respective to the downhole tool apparatus, is obtained, such that a coupling of the dart 300, that is respective to the downhole tool apparatus, to the downhole seat 216, that is respective to the downhole tool apparatus, is established and includes a seating of the dart 300, that is respective to the downhole tool apparatus, on the downhole seat 216, that is respective to the downhole tool apparatus. In this respect, in some embodiments, for example, for each one of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, the establishment of the coupled dart configuration, that is respective to the downhole tool apparatus, includes the establishment of the seated dart configuration 400 that is respective to the downhole tool apparatus.

In those embodiments where the plurality of downhole tool stations (e.g. 110, 112, 114) is a plurality of flow communication stations, and, for each one of the downhole tool stations, independently, the downhole tool apparatus, that is respective to the downhole tool station, is a flow control apparatus, such that a plurality of flow control apparatuses (e.g. apparatuses 200A, 200B, 200C) is established, and each one of the flow control apparatuses, independently, includes a respective flow communicator 208 (e.g. such as, for example, one or more ports) and a respective valve 210 (such as, for example, a sliding sleeve), and the flow communicator 208, that is respective to the flow control apparatus, co-operates with the valve 210, that is respective to the flow control apparatus, to define the flow control configuration that is respective to the flow control apparatus, such that the downhole tool, that is respective to the downhole tool apparatus, includes the valve 210 that is respective to the flow control apparatus, in some of embodiments, for example, for each one of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, the downhole seat 216, that is respective to the downhole tool apparatus, is coupled to the valve 210, that is respective to the downhole tool apparatus, such that the valve 210 translates with the seated dart configuration 400. In this respect, in some embodiments, for example, for each one of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, the dart 300, that is respective to the downhole tool apparatus, the downhole seat 216, that is respective to the downhole tool apparatus, and the valve 210, that is respective to the downhole tool apparatus, are co-operatively configured such that the coupling of the dart 300, that is respective to the downhole tool apparatus, to the downhole seat 216, that is respective to the downhole tool apparatus (e.g. the seating of the dart, that is respective to the downhole tool apparatus, on the downhole seat 216, that is respective to the downhole tool apparatus) establishes a coupling of the dart 300, that is respective to the downhole tool apparatus, to the valve 210, that is respective to the downhole tool apparatus, such that, in some embodiments, for example, the coupling of the dart 300, that is respective to the downhole tool apparatus, to the downhole tool 214, that is respective to the downhole tool apparatus, is the coupling of the dart 300, that is respective to the downhole tool apparatus, to the valve 210, that is respective to the downhole tool apparatus.

In those embodiments where each one of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, is configured for the transitioning from the first state to the second state, in some of these embodiments, for example, the establishment of the seated dart configuration, that is respective to the downhole tool apparatus, is for the transmitting of a force (e.g. a force that is, or is derived from, a fluid pressure force applied by fluid within the passage 106 of the wellbore string 104, such as that established by a fluid pressure differential within the passage 106 of the wellbore string 104) that is applied to the dart (e.g. in a downhole direction), that is respective to the downhole tool apparatus, for the motivating of the transitioning from the first state to the second state, with effect that the downhole operation is performed by the downhole tool 214 that is respective to the downhole tool apparatus. In those embodiments where each one of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, is configured for transitioning from the transition-ineffective first state, that is respective to the downhole tool apparatus, to the transition-effective first state, that is respective to the downhole tool apparatus, and also configured for transitioning from the transition-effective first state, that is respective to the downhole tool apparatus, to the second state, that is respective to the downhole tool apparatus, in some of these embodiments, for example, the establishment of the seated dart configuration 400, that is respective to the downhole tool apparatus, is for the transmitting of a force (e.g. a force that is, or is derived from, a fluid pressure force applied by fluid within the passage 106 of the wellbore string 104, such as that established by a fluid pressure differential within the passage 106 of the wellbore string 104) that is applied to the dart 300 (e.g. in the downhole direction), that is respective to the downhole tool apparatus, for the motivating of the transitioning from the transition-ineffective first state, that is respective to the downhole tool apparatus, to the transition-effective first state, that is respective to the downhole tool apparatus, and also for the transmitting of a force (e.g. a force that is, or is derived from, a fluid pressure force applied by fluid within the passage 106 of the wellbore string 104, such as that established by a fluid pressure differential within the passage 106 of the wellbore string 104) that is applied to the dart 300 (e.g. in the downhole direction), that is respective to the downhole tool apparatus, for the motivating of the transitioning from the transition-effective first state, that is respective to the downhole tool apparatus, to the second state, that is respective to the downhole tool apparatus, with effect that the downhole operation is performed by the downhole tool 214 that is respective to the downhole tool apparatus.

In some embodiments, for example, each one of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, includes a respective dart-occludable communicator 218 (e.g. an orifice) extending through the downhole seat 216, that is respective to the downhole tool apparatus. In some of these embodiments, for example, for each one of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, the dart 300, that is respective to the downhole tool apparatus, the downhole seat 216, that is respective to the downhole tool apparatus, and the dart-occludable communicator 218, that is respective to the downhole tool apparatus, are co-operatively configured such that, while the dart 300, that is respective to the downhole tool apparatus, is seated on the downhole seat 216, that is respective to the downhole tool apparatus (i.e. the seated valve configuration, that is respective to the downhole tool apparatus, is established), the dart-occludable communicator 218, that is respective to the downhole tool apparatus, is occluded by the dart 300, that is respective to the downhole tool apparatus, a respective wellbore isolation-controlling valve configuration 404 is established. In this respect, in some embodiments, for example, for each one of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, the dart 300, that is respective to the downhole tool apparatus, the downhole seat 216, that is respective to the downhole tool apparatus, and the dart-occludable communicator 218, that is respective to the downhole tool apparatus, are co-operatively configured such that, while the wellbore isolation-controlling valve configuration 404, that is respective to the downhole tool apparatus, is established, the wellbore isolation-controlling valve configuration 404, that is respective to the downhole tool apparatus, co-operates with the wellbore string 104 such that a respective sealing interface 404S (see FIGS. 2, 4, and 6) is established within the wellbore string passage 106, such that there is an absence of flow communication, within the wellbore string passage 106, across the sealing interface 404S that is respective to the downhole tool apparatus (including absence of flow communication, via the dart-occludable communicator 218, that is respective to the downhole tool apparatus), and, therefore, an absence of flow communication between a respective portion of the wellbore string passage 104 that is disposed uphole relative to the sealing interface 404S, that is respective to the downhole tool apparatus, and a respective portion of the wellbore string passage 104 that is disposed uphole relative to the sealing interface 404S that is respective to the downhole tool apparatus.

In those embodiments where, for each one of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, the dart 300, that is respective to the downhole tool apparatus, the downhole seat 216, that is respective to the downhole tool apparatus, and the dart-occludable communicator 218, that is respective to the downhole tool apparatus, are co-operatively configured such that, while the wellbore isolation-controlling valve configuration 404, that is respective to the downhole tool apparatus, is established, and the wellbore isolation-controlling valve configuration 404, that is respective to the downhole tool apparatus, is co-operating with the wellbore string 104 such that a respective sealing interface 404S is established within the wellbore string passage 106, in some of these embodiments, for example, a milling out of the wellbore isolation-controlling valve configuration 404, that is respective to the downhole tool apparatus, motivates defeating of the sealing interface, that is respective to the downhole tool apparatus.

In those embodiments where, for each one of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, the dart 300, that is respective to the downhole tool apparatus, the downhole seat 216, that is respective to the downhole tool apparatus, and the dart-occludable communicator 218, that is respective to the downhole tool apparatus, are co-operatively configured such that, while the wellbore isolation-controlling valve configuration 404, that is respective to the downhole tool apparatus, is established, and the wellbore isolation-controlling valve configuration 404, that is respective to the downhole tool apparatus, includes degradable material, and the wellbore isolation-controlling valve configuration 404, that is respective to the downhole tool apparatus, is co-operating with the wellbore string 104 such that a respective sealing interface 404S is established within the wellbore string passage 106, in some of these embodiments, for example, an emplacement of a degradation-promoting chemical agent in mass transfer communication with degradable material of the wellbore isolation-controlling valve configuration 404, that is respective to the downhole tool apparatus, motivates defeating of the sealing interface 404S that is respective to the downhole tool apparatus. In some embodiments, for example, the degradable material is a dissolvable metal material. In some embodiments, for example, the degradable material includes at least one of degradable aluminium and degradable magnesium. In some embodiments, for example, the degradation-promoting agent is a chemical agent, such as, for example, an acid. In some embodiments, for example, the degradation-promoting agent is wellbore fluids.

In some embodiments, for example, the one(s) of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), that is (are) disposed downhole relative to the furthest uphole one of the “N” downhole tool apparatuses (e.g. apparatus 200A), define a total number of “N−1” downhole one(s) (e.g. apparatuses 200B, 200C) of the “N” downhole tool apparatuses, and for each one of the “N−1” downhole one(s) of the “N” downhole tool apparatuses (e.g. apparatuses 200B, 200C), independently, a respective one or more uphole one(s) of the “N” downhole tool apparatuses is (are) disposed uphole relative to the downhole one of the “N” downhole tool apparatuses, such that for the ith downhole one, of the “N−1” downhole ones of the “N” downhole tool apparatuses”, the one or more uphole-disposed downhole tool apparatus(es), that is(are) respective to the downhole one of the “N” downhole tool apparatuses, is a total number of (i−1) uphole-disposed downhole tool apparatus(es) that is (are) respective to the downhole one of the “N” downhole tool apparatuses. For each one of the downhole ones of the “N” downhole tool apparatuses, independently, the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, the downhole one of the “N” downhole tool apparatus, and the one or more uphole-disposed downhole tool apparatus(es), that is(are) respective to the downhole one of the “N” downhole tool apparatuses are co-operatively configured such that conveyance of the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, via the passage 106 of the wellbore string 104, to the downhole one of the “N” downhole tool apparatuses (such as, for example, the displacement of the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, from the surface 10 to the downhole one of the “N” downhole tool apparatuses via the passage 106 of the wellbore string 104), such that the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, traverses the one or more uphole-disposed downhole tool apparatus(es) that is(are) respective to the downhole one of the “N” downhole tool apparatuses, is with effect that: (i) for each one of the one or more uphole-disposed downhole tool apparatus(es) that is(are) respective to the downhole one of the “N” downhole tool apparatuses, independently, the uphole-disposed downhole tool apparatus, that is respective to the downhole one of the “N” downhole tool apparatus, is traversed by the dart 300 that is respective to the downhole one of the “N” downhole tool apparatuses, (ii) for each one of the one or more uphole-disposed downhole tool apparatus(es) that is(are) respective to the downhole one of the “N” downhole tool apparatuses, independently, there is an absence of activation of the downhole tool (e.g. flow communication, via the flow communicator 208, between the wellbore 102 and the subterranean formation 100) that is respective to the uphole-disposed downhole tool apparatus that is respective to the downhole one of the “N” downhole tool apparatuses, by the dart 300 that is respective to the downhole one of the “N” downhole tool apparatuses, and (iii) the co-operative emplacement of the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, relative to the downhole tool, that is respective to the downhole one of the “N” downhole tool apparatuses, is established (and, in some embodiments, the seated dart configuration 400, that is respective to the downhole one of the “N” downhole tool apparatuses, is established, and, in some of these embodiments, for example, the wellbore isolation-controlling valve configuration 404, that is respective to the downhole one of the “N” downhole tool apparatuses, is also established, and, in some of these embodiments, for example, the sealing interface 404S, that is respective to the downhole one of the “N” downhole tool apparatuses, is also established).

In some of these embodiments, for example, the conveying is with additional effect that, for each one of the “N−1” downhole one(s) of the “N” downhole tool apparatuses (e.g. apparatuses 200B, 200C), independently, and for each one of the one or more uphole-disposed downhole tool apparatus(es), that is (are) respective to the downhole one of the “N” downhole tool apparatuses, independently, there is an absence of seating of the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, on the seat 216 that is respective to the uphole-disposed downhole tool apparatus that is respective to the downhole one of the “N” downhole tool apparatuses (such as, for example, an absence of establishment of the seated dart configuration 400 that is respective to the uphole-disposed downhole tool apparatus that is respect to the downhole one of the “N”downhole tool apparatuses).

In some embodiments, for example, for each one of the “N−1” downhole one(s) of the “N” downhole tool apparatuses (e.g. apparatuses 200B, 200C), independently, and for each one of the one or more uphole-disposed downhole tool apparatus(es), that is(are) respective to the downhole one of the “N” downhole tool apparatuses, independently, the dart-occludable communicator 218, that is respective to the uphole-disposed downhole tool apparatus that is respective to the downhole one of the “N” downhole tool apparatuses, and the dart 300, that is respective to the downhole one of the “N” downhole tool apparatus, are co-operatively configured such that the traversal, of the uphole-disposed downhole tool apparatus, that is respective to the downhole one of the “N” downhole tool apparatuses, by the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, and which is motivated by the conveying of the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, is through the dart-occludable communicator 218 that is respective to the uphole-disposed downhole tool that is respective to the downhole one of the “N” downhole tool apparatuses.

In some embodiments, for example, for each one of the “N” downhole tool apparatuses (200A, 200B, 200C), independently, the dart 300, that is respective to the downhole tool apparatus, is configurable in a coupling-effective configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus.

In some embodiments, for example, for each one of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, the dart 300, that is respective to the downhole tool apparatus, and the downhole tool apparatus are co-operatively configured such that, while the dart 300, that is respective to the downhole tool apparatus, is traversing the downhole tool apparatus, and is disposed in the coupling-effective configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus, the dart 300, that is respective to the downhole tool apparatus, becomes coupled to the downhole tool, that is respective to the downhole tool apparatus (and, in some of these embodiments, for example, becomes seated on the downhole seat, that is coupled to the downhole tool 214, that is respective to the downhole tool apparatus), such that the coupled dart configuration 400, that is respective to the downhole tool apparatus, is established.

In some embodiments, for example, for each one of the “N−1” downhole ones of the “N” downhole tool apparatuses, independently (and, in some of these embodiments, for example, for each one of the “N” downhole tool apparatuses, independently), the dart 300, that is respective to the downhole tool apparatus, is further configurable in a coupling-ineffective configuration, that is respective to the dart that is respective to the downhole tool apparatus, and, in some of these embodiments, for example, is configured for transitioning from the coupling-ineffective configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus, to the coupling-effective configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus.

In some embodiments, for example, for each one of the “N−1” downhole ones of the “N” downhole tool apparatuses, independently (and, in some of these embodiments, for example, for each one of the “N” downhole tool apparatuses, independently), the dart 300, that is respective to the downhole tool apparatus, and the downhole tool apparatus are co-operatively configured such that, while the dart 300 is disposed in the coupling-ineffective configuration, that is respective to the dart that is respective to the downhole tool apparatus, the dart 300, that is respective to the downhole tool apparatus is:

• • (i) ineffective for coupling to the downhole tool that is respective to the downhole tool apparatus to which the dart is respective; and
  • (ii) effective for transitioning to the coupling-effective configuration that is respective to the dart that is respective to the downhole tool apparatus.

In some of these embodiments, for example, for each one of the “N−1” downhole ones of the “N” downhole tool apparatuses, independently (and, in some of these embodiments, for example, for each one of the “N” downhole tool apparatuses, independently), the dart 300, that is respective to the downhole tool apparatus, and the downhole tool apparatus are co-operatively configured such that, while the dart 300 is disposed in the coupling-ineffective configuration, that is respective to the dart that is respective to the downhole tool apparatus, the dart 300, that is respective to the downhole tool apparatus is effective for transitioning to the coupling-effective configuration that is respective to the dart that is respective to the downhole tool apparatus, only.

In some embodiments, for example, for each one of the “N−1” downhole ones of the “N” downhole tool apparatuses, independently, the dart 300, that is respective to the downhole tool apparatus, and the downhole tool apparatus are co-operatively configured such that, while the dart 300 disposed is in the coupling-ineffective configuration, that is respective to the dart that is respective to the downhole one of “N” downhole tool apparatuses, the dart 300, that is respective to the downhole one of the “N”downhole tool apparatuses is:

• • (i) ineffective for coupling to: (a) the one or more uphole-disposed downhole tool apparatus(es), that is (are) respective to the downhole one of the “N” downhole tool apparatuses, and (b) the downhole one of the “N” downhole tool apparatuses; and
  • (ii) effective for transitioning to the coupling-effective configuration that is respective to the dart that is respective to the downhole tool apparatus.

In some of these embodiments, for example, for each one of the “N−1” downhole ones of the “N” downhole tool apparatuses, independently), the dart that is respective to the downhole one of the “N” downhole tool apparatuses, and the downhole tool apparatus are co-operatively configured such that, while the dart 300 is disposed in the coupling-ineffective configuration, that is respective to the dart that is respective to the downhole one of the “N” downhole tool apparatuses, the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses is effective for transitioning to the coupling-effective configuration that is respective to the dart that is respective to the downhole one of the “N”downhole tool apparatuses, only.

In some embodiments, for example, for each one of the “N−1” downhole ones of the “N” downhole tool apparatuses, independently (and, in some of these embodiments, for example, for each one of the “N” downhole tool apparatuses, independently), the transitioning of the dart 300, that is respective to the downhole tool apparatus, from the coupling-ineffective configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus, to the coupling-effective configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus, is with effect that the dart 300, that is respective to the downhole tool apparatus, expands in size, from a retracted configuration to an expanded configuration (e.g. by a radial expansion), such that, in some of those embodiments where the downhole tool apparatus includes the respective seat 216, through which extends the dart-occludable communicator 218, that is respective to the downhole tool apparatus, the expansion in size is with effect that the dart 300, that is respective to the downhole tool apparatus, becomes oversized relative to the dart-occludable communicator 218, that is respective to the downhole tool apparatus, such that the dart 300, that is respective to the downhole tool apparatus, is prevented from passing through the dart-occludable communicator 218, that is respective to the downhole tool apparatus. In some of these embodiments, for example, for each one of the “N−1” downhole ones of the “N” downhole tool apparatuses, independently (and, in some of these embodiments, for example, for each one of the “N” downhole tool apparatuses, independently), the transitioning of the dart 300, that is respective to the downhole tool apparatus, from the coupling-ineffective configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus, to the coupling-effective configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus, is effectuated by a radial expansion of the dart 300 that is respective to the downhole tool apparatus.

In some embodiments, for example, the system 5 includes, for each one of the “N−1” downhole ones of the “N” downhole tool apparatuses, independently (and, in some of these embodiments, for example, for each one of the “N” downhole tool apparatuses, independently), a respective proximity triggering configuration 220 configured for activating the transitioning of the dart 300, that is respective to the downhole tool apparatus, from the coupling-ineffective configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus, to the coupling-effective configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus, and the proximity triggering configuration 220, that is respective to the downhole tool apparatus, and the dart 300, that is respective to the downhole tool apparatus, are co-operatively configured such that, while the dart 300 is being conveyed through the wellbore string passage 106 and becomes disposed within sufficient proximity of the proximity triggering configuration, the transitioning of the dart 300, that is respective to the downhole tool apparatus, from the coupling-ineffective configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus, to the coupling-effective configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus, is activated. In some embodiments, for example, for each one of the “N−1” downhole ones of the “N” downhole tool apparatuses, independently (and, in some of these embodiments, for example, for each one of the “N” downhole tool apparatuses, independently), the proximity triggering configuration, that is respective to the downhole tool apparatus, is disposed within a next uphole downhole tool apparatus that is a next one of the one or more uphole ones of the “N” downhole tool apparatuses that is (are) disposed uphole relative to the downhole tool apparatus.

In some of these embodiments, for example, for each one of the “N−1” downhole ones of the “N” downhole tool apparatuses, independently (and, in some of these embodiments, for example, for each one of the “N” downhole tool apparatuses, independently), the proximity triggering configuration 220, that is respective to the downhole tool apparatus, is a field generator 220 (such as for example, any one of, or any combination of, a magnetic field generator 220 (e.g. one or more magnets), an electric field generator 220, an electromagnetic field generator 220, or a signal generator) for generating a transitioning-effective field to which the dart, that is respective to the downhole tool apparatus, is responsive (a suitable example of the responsiveness of the dart, that is respective to the downhole tool apparatus, to the generated transitioning-effective field is described in U.S. Pat. No. 11,753,887) such that the transitioning, from the coupling-ineffective configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus, to the coupling-effective configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus, is effectuated. In this respect, for each one of the “N−1” downhole ones of the “N” downhole tool apparatuses, independently (and, in some of these embodiments, for example, for each one of the “N” downhole tool apparatuses, independently), the field generator 220, that is respective to the downhole tool apparatus, and the dart 300, that is respective to the downhole tool apparatus, are co-operatively configured such that, while the field generator 220, that is respective to the downhole tool apparatus, is generating the transitioning-effective field within the passage 106, and while the dart 300, that is respective to the downhole tool apparatus, is being conveyed through the wellbore string passage 106 and becomes disposed within the transitioning-effective field, the transitioning of the dart 300, that is respective to the downhole tool apparatus, from the coupling-ineffective configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus, to the coupling-effective configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus, is activated. In some of these embodiments, for example, for each one of the “N−1” downhole ones of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently (and, in some of these embodiments, for example, for each one of the “N” downhole tool apparatuses, independently), the generated transitioning-effective field is disposed, within the passage 106, uphole relative to the flow communicator 208 that is respective to downhole tool apparatus 214. Also, in some of these embodiments, for example, for each one of at least the “N−1” downhole ones of the “N” downhole tool apparatuses, independently (and, in some of these embodiments, for example, for each one of the “N” downhole tool apparatuses, independently), the generated transitioning-effective field is disposed within the passage 106 and within a triggering zone disposed between the flow communicator 208, that is respective to the downhole tool apparatus, and the flow communicator 208 that is respective to the next uphole one of the “N” downhole tool apparatuses, only. As well, in some of these embodiments, for example, for each one of at least the “N−1” downhole ones of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently (and, in some of these embodiments, for example, for each one of the “N” downhole tool apparatuses, independently), the field generator 220, that is respective to the downhole tool apparatus, is emplaced sufficiently uphole relative to the location within the wellbore 102 at which the coupling between the dart 300, that is respective to the downhole tool apparatus, and the downhole tool 214, that is respective to the downhole tool apparatus, is effectuated (e.g. the coupling established by seating of the dart 300, that is respective to the downhole tool apparatus, on the seat 216 that is respective to the downhole tool apparatus), such that sufficient time is available for the transitioning of the dart 300, that is respective to the downhole tool apparatus, from the coupling-ineffective configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus, to the coupling-effective configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus, before arriving at the location within the wellbore at which the coupling between the dart 300, that is respective to the downhole tool apparatus, and the downhole tool 214, that is respective to the downhole tool apparatus, is effectuated.

In those embodiments where the system 5 includes, for each one of the “N−1” downhole ones of the “N” downhole tool apparatuses, independently (and, in some of these embodiments, for example, for each one of the “N” downhole tool apparatuses, independently), a respective proximity triggering configuration 220, configured for activating the transitioning of the dart 300, that is respective to the downhole tool apparatus, from the coupling-ineffective configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus, to the coupling-effective configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus, in some of these embodiments, for example, for each one of the “N−1” downhole ones of the “N” downhole tool apparatuses, independently (and, in some of these embodiments, for example, for each one of the “N” downhole tool apparatuses, independently), the dart 300, that is respective to the downhole tool apparatus, and the downhole tool apparatus are co-operatively configured such that, while the dart 300 is disposed in the coupling-ineffective configuration, that is respective to the dart that is respective to the downhole tool apparatus, the dart 300, that is respective to the downhole tool apparatus is:

• • (i) ineffective for coupling to the downhole tool apparatus to which the dart 300 is respective; and
  • (ii) co-operable with the proximity triggering configuration, that is respective to the downhole tool apparatus, such that, while the dart, that is respective to the downhole tool apparatus, is disposed within a field that is being generated by the proximity triggering configuration, that is respective to the downhole tool apparatus, transitioning of the dart, that is respective to the downhole tool apparatus, to the coupling-effective configuration, that is respective to the dart that is respective to the downhole tool apparatus, is effectuated.

In some of these embodiments, for example, for each one of the “N−1” downhole ones of the “N” downhole tool apparatuses, independently (and, in some of these embodiments, for example, for each one of the “N” downhole tool apparatuses, independently), the co-operability, of the dart 300 that is respective to the downhole tool apparatus, with the proximity triggering configuration that is respective to the downhole tool apparatus, is a co-operability with the proximity triggering configuration that is respective to the downhole tool apparatus, only.

In those embodiments where the system 5 includes, for each one of the “N−1” downhole ones of the “N” downhole tool apparatuses, independently, for example, a respective proximity triggering configuration 220, configured for activating the transitioning of the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, from the coupling-ineffective configuration, that is respective to the dart 300 that is respective to the downhole one of the “N” downhole tool apparatuses, to the coupling-effective configuration, that is respective to the dart 300 that is respective to the downhole one of the “N” downhole tool apparatuses, in some of these embodiments, for example, for each one of the “N−1” downhole ones of the “N” downhole tool apparatuses, independently, the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, and the downhole tool apparatus are co-operatively configured such that, while the dart 300 is disposed in the coupling-ineffective configuration, that is respective to the dart that is respective to the downhole one of the “N” downhole tool apparatuses, the dart 300, that is respective to the downhole tool apparatus is

• • (i) ineffective for coupling to: (a) the one or more uphole-disposed downhole tool apparatus(es), that is(are) respective to the downhole one of the “N” downhole tool apparatuses, and (b) the downhole one of the “N” downhole tool apparatuses; and
  • (ii) co-operable with the proximity triggering configuration, that is respective to the downhole one of the “N” downhole tool apparatuses, such that, while the dart, that is respective to the downhole one of the “N” downhole tool apparatuses, is disposed within a field that is being generated by the proximity triggering configuration, that is respective to the downhole one of the “N” downhole tool apparatuses, transitioning of the dart, that is respective to the downhole one of the “N” downhole tool apparatuses, to the coupling-effective configuration, that is respective to the dart that is respective to the downhole one of the “N”downhole tool apparatuses, is effectuated.

In some of these embodiments, for example, for each one of the “N−1” downhole ones of the “N” downhole tool apparatuses, independently, the co-operability, of the dart 300 that is respective to the downhole one of the “N” downhole tool apparatuses, with the proximity triggering configuration that is respective to the downhole one of the “N” downhole tool apparatuses, is a co-operability with the proximity triggering configuration that is respective to the downhole one of the “N” downhole tool apparatuses, only Also in those embodiments where the system 5 includes, for each one of the “N−1” downhole ones of the “N” downhole tool apparatuses, independently (and, in some of these embodiments, for example, for each one of the “N” downhole tool apparatuses, independently), a respective proximity triggering configuration 220 configured for activating the transitioning of the dart 300, that is respective to the downhole tool apparatus, from the coupling-ineffective configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus, to the coupling-effective configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus, for each one of at least the “N−1” downhole ones of the “N” downhole tool apparatuses, independently (and, in some of these embodiments, for example, for each one of the “N” downhole tool apparatuses, independently), in the coupling-effective configuration, that is respective to the dart that is respective to the downhole tool apparatus:

• • the dart, that is respective to the downhole tool apparatus, and the downhole tool apparatus are co-operatively configured such that the dart, that is respective to the downhole tool apparatus, is effective for coupling to the downhole tool that is respective to the downhole tool apparatus.

In some of these embodiments, for example, for each one of the “N−1” downhole ones of the downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently (and, in some of these embodiments, for example, for each one of the “N” downhole tool apparatuses, independently), the dart 300, that is respective to the downhole tool apparatus, includes a sensor, a controller, and an actuator for activating the transitioning based on the responsiveness of the dart 300, that is respective to the downhole tool apparatus, to the generated transitioning-effective field. In some embodiments, for example, the dart 300 autonomously senses its position within the passageway by sensing the presence of markers which may be disposed at spaced apart intervals along the length of the wellbore passage 106. In some embodiments, for example, the one or more markers are magnetic markers. By sensing the markers, the dart 300 may determine its downhole position within the passage 106 and selectively activate at the predetermined target location. Accordingly, in some embodiments, the device may “count” the markers as the device travels through the passage 106, the dart 300 thereby determining its position within the passage 106 based on a marker count.

For each one of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, a field generator 220, that is respective to the downhole tool apparatus, and is configured for generating a transitioning-effective field to which the dart, that is respective to the downhole tool apparatus, is responsive, such that the transitioning, from the coupling-ineffective configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus, to the coupling-effective configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus, is effectuated, the dart 300, that is respective to the furthest uphole one of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), and the field generator 220, that is respective to the furthest uphole one of the total number of “N” downhole tool apparatuses, are co-operatively configured such that, while the field generator 220, that is respective to the furthest uphole one of the “N” downhole tool apparatuses, is generating the transitioning-effective field within the passage 106, and while the dart 300, that is respective to the furthest uphole one of the total number of “N” downhole tool apparatuses, is being conveyed through the wellbore string passage 106 and becomes disposed within the transitioning-effective field, the transitioning of the dart 300, that is respective to the downhole tool apparatus, from the coupling-ineffective configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus, to the coupling-effective configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus, is activated.

In those embodiments where the one(s) of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), that is (are) disposed downhole relative to the furthest uphole one of the “N” downhole tool apparatuses (e.g. apparatus 200A), define a total number of “N−1” downhole one(s) (e.g. apparatuses 200B, 200C) of the “N” downhole tool apparatuses, and for each one of the “N−1” downhole one(s) of the “N” downhole tool apparatuses (e.g. apparatuses 200B, 200C), independently, a respective one or more uphole one(s) of the “N” downhole tool apparatuses is (are) disposed uphole relative to the downhole one of the “N” downhole tool apparatuses, such that for the i^th downhole one, of the “N−1” downhole ones of the “N” downhole tool apparatuses”, the one or more uphole-disposed downhole tool apparatus(es), that is(are) respective to the downhole one of the “N” downhole tool apparatuses, is a total number of (i−1) uphole-disposed downhole tool apparatus(es) that is(are) respective to the downhole one of the “N” downhole tool apparatuses, in some of these embodiments, for example, for each one of the “N−1” downhole one(s) of the “N” downhole tool apparatuses (e.g. apparatuses 200B, 200C), independently, the downhole one of the “N” downhole tool apparatuses, the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, and the one or more uphole-disposed downhole tool apparatus(es) that is(are) respective to the downhole one of the “N” downhole tool apparatuses, are co-operatively configured such that while the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, is disposed in the activation-enabled, coupling-ineffective configuration, that is respective to the dart 300 that is respective to the downhole one of the “N” downhole tool apparatuses, and being conveyed, via the passage 106 of the wellbore string 104, from the surface 10 to the downhole one of the “N” downhole tool apparatuses (such as, for example, the displacement of the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, from the surface 10 to the downhole one of the “N” downhole tool apparatuses via the passage 106 of the wellbore string 104), such that the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, is traversing the one or more uphole-disposed downhole tool apparatus(es), that is(are) respective to the downhole one of the “N” downhole tool apparatuses, for each one of the one or more uphole-disposed downhole tool apparatuses, that is(are) respective to the downhole one of the “N” downhole tool apparatuses, independently, the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, traverses the uphole-disposed downhole tool apparatus that is respective to the downhole one of the “N” downhole tool apparatuses, such that there is an absence of coupling of the dart, that is respective to the downhole one of the “N” downhole tool apparatuses, to the downhole tool 214, that is respective to the uphole-disposed downhole tool apparatus that is respective to the downhole one of the “N” downhole tool apparatuses, and such that the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, becomes disposed downhole relative to the uphole-disposed downhole tool apparatus that is respective to the downhole one of the “N” downhole tool apparatuses. In some of these embodiments, for example, for each one of the “N−1” downhole one(s) of the “N” downhole tool apparatuses (e.g. apparatuses 200B, 200C), independently, for the downhole one of the “N” downhole tool apparatuses, for each one of one or more uphole-disposed downhole tool apparatuses, that is(are) respective to the downhole one of the “N” downhole tool apparatuses, independently, the traversing of the uphole-disposed downhole tool apparatus, that is respective to the downhole one of the “N” downhole tool apparatuses, by the dart 300 that is respective to the downhole one of the “N” downhole tool apparatuses, such that there is an absence of coupling of the dart, that is respective to the downhole one of the “N” downhole tool apparatuses, to the downhole tool 214, that is respective to the uphole-disposed downhole tool apparatus that is respective to the downhole one of the “N” downhole tool apparatuses, includes conveyance of the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, through the dart-occludable communicator 218, that is respective to the uphole-disposed downhole tool apparatus that is respective to the downhole one of the “N” downhole tool apparatuses, such that there is an absence of seating of the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, on the seat 216, that is respective to the uphole-disposed downhole tool apparatus that is respective to the downhole one of the “N” downhole tool apparatuses, and such that the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, becomes disposed downhole relative to the uphole-disposed downhole tool apparatus that is respective to the downhole one of the “N”downhole tool apparatuses.

Also, for each one of the “N−1” downhole one(s) (e.g. apparatuses 200B, 200C) of the “N” downhole tool apparatuses, independently, the dart, that is respective to the downhole one of the “N” downhole tool apparatuses, and the downhole one of the “N” downhole tool apparatuses are co-operatively configured such that, while the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, is disposed in the coupling-ineffective configuration, that is respective to the dart that is respective to the downhole one of the “N” downhole tool apparatuses, and being conveyed, via the passage 106 of the wellbore string 104, from the surface 10 to the downhole one of the “N” downhole tool apparatuses, such that the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, becomes disposed within sufficient proximity of the proximity triggering configuration that is respective to the downhole one of the “N” downhole tool apparatuses, the transitioning of the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, from the coupling-ineffective configuration, that is respective to the dart 300 that is respective to the downhole one of the “N” downhole tool apparatuses, to the coupling-effective configuration, that is respective to the dart that is respective to the downhole one of the “N” downhole tool apparatuses, is effectuated by the field that is generated by the proximity triggering configuration that is respective to the downhole one of the “N” downhole tool apparatuses, such that the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, becomes effective for coupling to the downhole tool that is respective to the downhole one of the “N” downhole tool apparatuses for actuating the downhole operation by the downhole tool 216. In some of these embodiments, for example, the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, becomes seated on the seat 216, that is respective to the downhole one of the “N” downhole tool apparatuses, such that the seated dart configuration 400, that is respective to the downhole one of the “N” downhole tool apparatuses, becomes established (and, in some of these embodiments, for example, is also with effect that the wellbore isolation-controlling valve configuration, that is respective to the downhole one of the “N”downhole tool apparatuses, is also established).

Also, the dart, that is respective to the furthest uphole one of the “N” downhole tool apparatuses, and the furthest uphole one of the “N” downhole tool apparatuses are co-operatively configured such that, while the dart 300, that is respective to the furthest uphole one of the “N” downhole tool apparatuses, is traversing the furthest uphole one of the “N” downhole tool apparatuses, and becomes disposed in the coupling-effective configuration, that is respective to the dart 300 that is respective to the furthest uphole one of the “N” downhole tool apparatuses, the dart 300, that is respective to the furthest uphole one of the “N” downhole tool apparatuses, becomes coupled to the downhole tool 214, that is respective to the furthest uphole one of the “N” downhole tool apparatuses, and, in some of these embodiments, for example, the dart 300, that is respective to the furthest uphole one of the “N” downhole tool apparatuses, becomes seated on the seat 216, that is respective to the furthest uphole one of the “N” downhole tool apparatuses, such that the seated dart configuration 400, that is respective to the furthest uphole one of the “N” downhole tool apparatuses, becomes established (and, in some of these embodiments, for example, is also with effect that the wellbore isolation-controlling valve configuration, that is respective to the furthest uphole one of the “N” downhole tool apparatuses, is also established).

In some embodiments, for example, the one(s) of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), that is(are) disposed downhole relative to the furthest uphole one of the “N” downhole tool apparatuses (e.g. apparatus 200A), define a total number of “N−1” downhole one(s) of the “N” downhole tool apparatuses (e.g. apparatuses 200B, 200C), and for each one of the “N−1” downhole one(s) of the “N” downhole tool apparatuses (e.g. apparatuses 200B, 200C), independently, a respective one or more uphole one(s) of the “N” downhole tool apparatuses is(are) disposed uphole relative to the downhole one of the “N” downhole tool apparatuses, and for each one of the “N−1” downhole one(s) of the “N” downhole tool apparatuses, independently, the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, and is disposed in the coupling-effective configuration, and has become unintentionally disposed in the coupling-effective configuration, is susceptible to coupling to the downhole tool 214 that is respective to a one of the one or more of the uphole one(s) of the “N” downhole tool apparatuses (e.g. the furthest uphole one of the “N” downhole tool apparatuses, such as, for example, apparatus 200A), that is(are) respective to the downhole one of the “N” downhole tool apparatuses, such that an unintentional coupling to the downhole tool 214 that is respective to the one of the one or more uphole ones of the “N” downhole tool apparatuses, that is (are) respective to the downhole one of the “N” downhole tool apparatuses, is established. In some embodiments, for example, the system 5 is configured for mitigating the risk, for each one of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, of premature activation of the transitioning of the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, from the coupling-ineffective configuration, that is respective to the dart 300 that is respective to the downhole one of the “N” downhole tool apparatuses, to the coupling-effective configuration, that is respective to the dart 300 that is respective to the downhole one of the “N” downhole tool apparatuses (such as, for example, a premature activation that occurs, within the wellbore string passage 106, uphole relative to the furthest uphole one of the “N” downhole tool apparatuses).

In this respect, referring to FIG. 8, in those embodiments where each one of the series of “N−1” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently (and, in some of these embodiments, each one of the series of “N” downhole tool apparatuses, independently), includes a respective field generator 220 configured for generating a field, and the dart 300, that is respective to the downhole tool apparatus, is responsive to the generated field, and the dart 300, that is respective to the downhole tool apparatus, and the field generator 220, that is respective to the downhole tool apparatus, are co-operatively configured such that, while the field generator 220, that is respective to the downhole tool apparatus, is generating a transitioning-effective field within the passage 106 of the wellbore string 104, and the dart 300, that is respective to the downhole tool apparatus, and disposed in the coupling-ineffective configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus, is being conveyed within the passage 106 and through the generated field, the dart 300, that is respective to the downhole tool apparatus, responds to the generated transitioning-effective field with effect that the transitioning from the coupling-ineffective configuration, that is respective to the dart that is respective to the downhole tool apparatus, to the coupling-effective configuration, that is respective to the dart that is respective to the downhole tool apparatus, is effectuated, in some of these embodiments, for example, for each one of the “N−1” downhole one(s) (e.g. apparatuses 200B, 200C) of the “N” downhole tool apparatuses, independently (and, in some of these embodiments, for example, for each one of the “N” downhole tool apparatuses, independently), for the dart 300, that is respective to the downhole tool apparatus, the coupling-ineffective configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus, is an activation-enabled, coupling-ineffective configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus, and the dart 300, that is respective to the dart 300 that is respective to downhole tool apparatus is further configurable in an activation-disabled configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus, and is configured for transitioning from the activation-disabled configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus, to the activation-enabled, coupling-ineffective configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus. In this respect, for each one of the “N−1” downhole one(s) of the “N” downhole tool apparatuses, independently (and, in some of these embodiments, for example, for each one of the “N” downhole tool apparatuses, independently), in the activation-disabled configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus, the dart 300, that is respective to the downhole tool apparatuses, is disabled from transitioning to the coupling-effective configuration that is respective to the dart 300 that is respective to the downhole tool apparatus.

In some of these embodiments, for example, an activation tool configuration 700 is integrated (e.g. via threaded coupling) within the wellbore string 104 for activating transitioning of, for each one of the “N−1” downhole one(s) of the “N” downhole tool apparatuses (and, in some of these embodiments, for example, for each one of the “N” downhole tool apparatuses, independently), the dart 300, that is respective to the downhole tool apparatus, from the activation-disabled configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus, to the activation-enabled, coupling-ineffective configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus, within an activation zone 702 (of the wellbore string passage 106), only. In some embodiments, for example, the activation tool configuration 700 (and, in some embodiments, for example, the activation zone 702) is spaced apart from the seat 216, that is respective to the furthest uphole one of the “N” downhole tool apparatuses, by a maximum distance of no more than 40 feet (such as, for example, no more than 35 feet, such as, for example, no more than 30 feet, such as, for example, no more than 25 feet), as measured along the central longitudinal axis 102A of the wellbore 102. In some embodiments, for example, the activation zone 702 is spaced apart from the seat 216, that is respective to the furthest uphole one of the “N” downhole tool apparatuses, by a maximum distance of no more than 40 feet (such as, for example, no more than 35 feet, such as, for example, no more than 30 feet, such as, for example, no more than 25 feet), as measured along the central longitudinal axis 102A of the wellbore 102. In this respect, in some embodiments, for example, for each one of the “N−1” downhole one(s) of the “N” downhole tool apparatuses (and, in some of these embodiments, for example, for each one of the “N” downhole tool apparatuses, independently), transitioning the dart 300, that is respective to the downhole tool apparatus from the actuation-disabled configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus, to the actuation-enabled, coupling-ineffective configuration, that is respective dart 300 that is respective to the downhole tool apparatus, with the activation tool configuration 700, as close as possible to the furthest uphole one of the “N” downhole tool apparatuses, reduces the opportunity for exposing the dart 300 to false signals (such as, for example, signals outside of the activation zone 702), which, in those embodiments where the dart 300 is configured for counting sleeves, could result in an erroneous count and seating of the dart 300 at an unintended stage. In some embodiments, for example, the activation tool configuration 700 is spaced apart from the seat 216, that is respective to furthest uphole one of the “N” downhole tool apparatuses, by a minimum distance of at least 12 feet (such as, for example, at least 15 feet), as measured along the central longitudinal axis 102A of the wellbore 102. In some embodiments, for example, the activation zone 702 is spaced apart from the seat 216, that is respective to the furthest uphole one of the “N” downhole tool apparatuses, by a minimum distance of at least 12 feet (such as, for example, at least 15 feet), as measured along the central longitudinal axis 102A of the wellbore 102.

In some embodiments, for example, the activation tool configuration 700 includes a proximity triggering configuration 706 for effectuating the activation of the transitioning of, for each one of the “N−1” downhole one(s) of the “N” downhole tool apparatuses independently, (and, in some of these embodiments, for example, for each one of the “N” downhole tool apparatuses, independently), the dart 300, that is respective to the downhole tool apparatus, from the activation-disabled configuration, that is respective to the dart that is respective to the downhole tool apparatus, to the activation-enabled, coupling-ineffective configuration, that is respective to the dart that is respective to the downhole tool apparatus, within the activation zone 702 (of the wellbore string passage 106), only. In this respect, for each one of the “N−1” downhole one(s) of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently (and, in some of these embodiments, for example, for each one of the “N” downhole tool apparatuses, independently), the dart 300, that is respective to the downhole tool apparatus, and the activation tool configuration 700 are co-operatively configured such that, while the dart 300, that is respective to the downhole tool apparatus, is being conveyed downhole, through the passage 106 of the wellbore string 104, and becomes disposed in sufficient proximity to the proximity triggering configuration 706, the proximity triggering configuration 706 activates transitioning of the dart 300, that is respective to the downhole tool apparatus, from the activation-disabled, configuration, that is respective to the dart that is respective to the downhole tool, to the activation-enabled, coupling-ineffective configuration, that is respective to the dart that is respective to the downhole tool, within the activation zone 702. In some embodiments, for example, the proximity triggering configuration 706 is a field generator (such as for example, any one of, or any combination of, a magnetic field generator (e.g. one or more magnets), an electric field generator, or electromagnetic field generator, or signal generator) for generating an activation field, within the activation zone 702 only, for activating the transitioning of the dart 300, that is respective to the downhole tool apparatus, from the activation-disabled configuration, that is respective to the dart that is respective to the downhole tool apparatus, to the activation-enabled, coupling-ineffective configuration, that is respective to the dart that is respective to the downhole tool apparatus, while the dart 300, that is respective to the downhole tool apparatus, is disposed within the generated activation field. In this respect, in some embodiments, for example, for each one of the “N−1” downhole one(s) of the “N” downhole tool apparatuses, independently (and, in some of these embodiments, for example, for each one of the “N” downhole tool apparatuses, independently), the dart 300, that is respective to the downhole tool apparatus, and the activation tool configuration 700 are co-operatively configured such that, while the dart 300, that is respective to the downhole tool apparatus, is being conveyed downhole, in the activation-disabled configuration, that is respective to the dart 300 that is respective to the downhole tool apparatus, the dart 300, that is respective to the downhole tool apparatus, becomes disposed within the activation field generated by the field generator, and the activation is a response to the emplacement of the dart, that is respective to the downhole tool apparatus, within the activation field that is being generated by the field generator that is respective to the downhole tool apparatus. In some embodiments, for example, for each one of at least the “N−1” downhole ones of the “N” downhole tool apparatuses, independently (and, in some of these embodiments, for example, for each one of the “N” downhole tool apparatuses, independently), the transitioning of the dart 300, that is respective to the downhole tool apparatus, from the activation-disabled configuration, that is respective to the dart that is respective to the downhole tool apparatus, to the activation-enabled, coupling-ineffective configuration, that is respective to the dart that is respective to the downhole tool apparatus, is activated in response to emplacement, of the dart 300, that is respective to the downhole tool apparatus, within a field, only (whether generated by the configuration 706, or otherwise, or whether within the activation zone 702, or otherwise).

Advantageously, for each one of the “N−1” downhole one(s) (e.g. apparatuses 200B, 200C) of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, and the uphole-disposed downhole tool apparatus(es), that is(are) respective to the downhole one of the “N” downhole tool apparatuses, are co-operatively configured such that, while the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, is being conveyed downhole, in the activation-disabled configuration, through the portion of the passage 106 that is disposed uphole relative to the activation zone 702, the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, is conveyed through a field (such as, for example, any one of, or any combination of, a magnetic field, an electric field, or an electromagnetic field), there is an absence of transitioning of the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, to a prematurely activated configuration, such that, after having been conveyed through the field, the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, traverses the uphole-disposed downhole tool apparatus(es), that is(are) respective to the downhole one of the “N” downhole tool apparatuses (including the furthest uphole one of the “N” downhole tool apparatuses), and becomes coupled to the downhole tool that is respective to the downhole one of the “N”downhole tool apparatuses.

In this respect, for each one of the “N−1” downhole ones (e.g. apparatuses 200A, 200B) of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, by configuring the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, such that premature actuation of the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, is at least mitigated, the risk, of the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, becoming inadvertently coupled to the downhole tool that is respective to a one of the uphole-disposed downhole tool apparatus(es), that is(are) respective to the downhole one of the “N” downhole tool apparatuses, is at least mitigated. Such inadvertent coupling could render production of reservoir fluid from the subterranean formation, via the wellbore, to be unsuitable. Such risks are present where fields, present in the vicinity of the passage 106 of the wellbore string, are present which could prematurely, and inadvertently, transition the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, to a configuration which would result in the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, becoming coupled to the downhole tool that is respective to (e.g. seated on the seat 216 that is respective to) one of the uphole-disposed downhole tool apparatuses that is(are) respective to the downhole one of the “N” downhole tool apparatuses.

For example, a magnetic field is typically present in a drill string 704, after a drilling operation, and using the drill string 704 (after, for example, the drill string 704 has been used to run in a liner string for completing the well), by subsequently deploying a dart, that is respective to a downhole tool apparatus, through the drill string 704, could result in the premature, and inadvertent, transitioning of the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, to a configuration which would result in the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, becoming unintentionally coupled to the downhole tool that is respective to (e.g. seated on the seat 216 that is respective to) a one of the uphole-disposed downhole tool apparatuses that is(are) respective to the dart 300 that is respective to the downhole one of the “N” downhole tool apparatuses. In some of these embodiments, for example, the activation tool configuration 700 includes a magnetic field generator, and is disposed downhole relative to the drill string 704, for generating a magnetic field for effectuating the activation of the transitioning of the dart 300 that is respective to the downhole one of the “N” downhole tool apparatuses, from the activation-disabled configuration, that is respective to the dart 300 that is respective to the downhole one of the “N” downhole tool apparatuses, to the actuation-enabled, coupling-ineffective configuration, that is respective to the dart 300 that is respective to the downhole one of the “N” downhole tool apparatuses, and the transitioning of the dart 300, that is respective to a downhole one of the “N” downhole tool apparatuses, from the activation-disabled configuration, that is respective to the dart 300 that is respective to the downhole one of the “N” downhole tool apparatuses to the actuation-enabled, coupling-ineffective configuration, that is respective to the dart 300 that is respective to the downhole one of the “N” downhole tool apparatuses, is effectuated in response to the activation effectuated by the generated magnetic field, while ignoring the magnetic field present within the drill string 704 such that there is an absence of the transitioning by the magnetic field present within the drill string 704. In this respect, in such embodiments, for example, the generated magnetic field is distinct from the magnetic field that is present within the drill string 704.

In some embodiments, for example, for each one of the “N−1” downhole ones (e.g. apparatuses 200A, 200B) of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, the system 5 is configured for mitigating the consequences of premature activation of the transitioning of the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses the coupling-effective configuration.

In this respect, referring to FIG. 9, in some embodiments, for example, a landing tool apparatus 800 is integrated within (e.g. via threaded coupling, at uphole and downhole ends of the apparatus 800, to) the wellbore string 104, between an uphole wellbore string section, of one of a casing or a liner, and a downhole wellbore string section, of one of a casing or a liner, and emplaced uphole relative to the “N” downhole tool apparatuses, and, therefore the furthest uphole one of the “N” downhole tool apparatuses. In some embodiments, for example, the landing tool apparatus 800 is separated from the furthest uphole one of the “N” downhole tool apparatuses by an intermediate wellbore string, at least a portion of which is an intermediate casing. In some embodiments, for example, the landing tool apparatus 800 is connected to the intermediate casing, such as by, for example, a threaded connection. In some embodiments, for example, the intermediate casing is a casing string.

The landing tool apparatus 800 includes a landing seat 802 and, in some embodiments, for example, includes a pass-through communicator 804 (e.g. an orifice) extending through the landing seat 802. In some embodiments, for example, the pass-through communicator 804 defines a total cross-sectional flow area of at least 33 square inches, such as, for example, at least 35 square inches, such as, for example, at least 38 square inches. For each one of the “N−1” downhole ones (e.g. apparatuses 200A, 200B) of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, and the landing tool configuration 800 are co-operatively configured such that, while the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, is disposed in the coupling-ineffective configuration, that is respective to the dart 300 that is respective to the downhole one of the “N” downhole tool apparatuses, and being conveyed downhole such that the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, is traversing the landing tool configuration 800, the dart passes through the landing seat (and, in some embodiments, the pass-through communicator 218) such that the dart, that is respective to the downhole one of the “N” downhole tool apparatuses, becomes disposed downhole relative to the landing tool apparatus 800. Also, for each one of the “N−1” downhole ones (e.g. apparatuses 200A, 200B) of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, and the landing tool configuration 800 are co-operatively configured such that, while the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, is disposed in the coupling-effective configuration, and being conveyed downhole such that the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, is traversing the landing tool configuration 800, the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, becomes seated (such as, for example, landed) on the landing seat 802, with effect that the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, is prevented from being displaced downhole relative to the landing tool apparatus 800, and such that the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, and the landing tool apparatus 800 are co-operating to establish a landed dart configuration.

For each one of the “N−1” downhole ones (e.g. apparatuses 200A, 200B) of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, and is disposed in the coupling-effective configuration, and has become unintentionally disposed in the coupling-effective configuration such that the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, becomes susceptible to coupling to the downhole tool that is respective to a one of the one or more of the uphole one(s) of the “N” downhole tool apparatuses (e.g. the furthest uphole one of the “N” downhole tool apparatuses, such as, for example, apparatus 200A), that is(are) respective to the downhole one of the “N” downhole tool apparatuses, such that an unintentional coupling to the downhole tool that is respective to one of the one or more uphole ones of the “N” downhole tool apparatuses, that is(are) respective to the downhole one of the “N” downhole tool apparatuses, is established. In some embodiments, for example, such unintentional coupling could result in an unintentional opening of the valve 210, that is respective to the one of the one or more uphole one(s) of the “N” downhole tool apparatuses, that is(are) respective to the downhole one of the “N” downhole tool apparatuses, and, where the valve 210, that is respective to the one of the one or more uphole one(s) of the “N” downhole tool apparatuses, that is(are) respective to the downhole one of the “N” downhole tool, is closeable, this could cause costly operational delays, and where the valve 210, that is respective to the one of the one or more uphole one(s) of the “N” downhole tool apparatuses, that is(are) respective to the downhole one of the “N” downhole tool, is not closeable, this could result in abandonment of the well at considerable costs. For each one of the downhole one(s) of the “N” downhole tool apparatuses, independently, the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, and the landing tool apparatus 800 are co-operatively configured such that, while the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, is being conveyed through the passage 106, the consequences of such unintentional coupling, arising from the unintentional transitioning of the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, to the coupling-effective configuration, that is respective to the dart 300 that is respective to the downhole one of the “N” downhole tool apparatuses, is mitigated by intercepting the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, and has become disposed in the coupling-effective configuration, that is respective to the dart 300 that is respective to the downhole one of the “N” downhole tool apparatuses, at a location that is uphole relative to the furthest uphole one the “N” downhole tool apparatuses (i.e. before the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, reaches the furthest uphole one of the “N” downhole tool apparatuses). In this respect, for each one of the “N−1” downhole one(s) of the “N” downhole tool apparatuses, independently, the landing tool apparatus 800 is effective for effectuating the intercepting of the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, and has become disposed in the coupling-effective configuration, that is respective to the dart 300 that is respective to the downhole one of the “N” downhole tool apparatuses, before the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, reaches the furthest uphole one of the “N” downhole tool apparatuses.

In some embodiments, for example, the landing seat 802, of the landing tool apparatus 800, is spaced apart from the furthest uphole one of the “N” downhole tool apparatuses (and, in some embodiments, for example, the seat 216, that is respective to the furthest uphole one of the “N” downhole tool apparatuses) by a maximum distance of no more than 40 feet (such as, for example, no more than 35 feet, such as, for example, no more than 30 feet, such as, for example, no more than 25 feet), as measured along the central longitudinal axis 102A of the wellbore 102. In this respect, in some embodiments, for example, emplacing the landing seat 802 as close as possible to the furthest uphole one of the “N” downhole tool apparatuses, reduces the opportunity for a falsely activated dart, that is respective to the downhole one of the “N” downhole tool apparatuses, from becoming unintentionally seated on the seat of the furthest uphole one of the “N” downhole tool apparatuses. In some embodiments, for example, the landing seat 802 is spaced apart from the furthest uphole one of the “N” downhole tool apparatuses by a minimum distance of at least 12 feet (such as, for example, at least 15 feet), as measured along the central longitudinal axis 102A of the wellbore 102.

In some of these embodiments, for example, there is an absence of configurability of the landing tool apparatus 800 for establishing flow communication between the wellbore string passage 106 and the subterranean formation 100 (such as, for example, by opening of a flow communicator in response to displacement of a valve (e.g. sleeve), relative to the flow communicator, such displacement, in some embodiments, being actuated in response to a fluid pressure force being applied to a landed dart configuration).

In those embodiments where, for each one of the “N−1” downhole ones (e.g. apparatuses 200A, 200B) of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, where the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, and the landing tool apparatus 800 are co-operating to establish the landed dart configuration, in some of these embodiments, for example, the landed dart configuration is sufficiently strong to withstand a pressure differential, that is established between a space, within the wellbore string passage 106, disposed uphole relative to the landed dart configuration, and a space, within the wellbore string passage 106, disposed downhole relative to the landed dart configuration (e.g. across the landed dart configuration), of at least.4,000 psi (such as, for example, at least 5,000 psi, such as, for example, at least 6000 psi, such as, for example, at least 7,000 psi, such as, for example, at least 8,000 psi) such that, while the pressure differential is being applied, there is an absence of defeating of the seating of the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, on the landing seat 802 (and, in some of these embodiments, for example, the absence of defeating of the seating is an absence of extrusion of the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, through the communicator 804 of the landing seat 802).

In those embodiments where, for each one of the “N−1” downhole ones (e.g. apparatuses 200A, 200B) of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, where the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, and the landing tool apparatus 800 are co-operating to establish the landed dart configuration, in some of these embodiments, for example, the landed dart configuration is sufficiently strong to withstand a pressure differential, that is established between a space, within the wellbore string passage 106, disposed uphole relative to the landed dart configuration, and a space, within the wellbore string passage 106, disposed downhole relative to the landed dart configuration, that exceeds the strength of the dart 300, such that, while the pressure differential is being applied, (e.g. across the landed dart configuration) is an absence of defeating of the seating of the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, on the landing seat 802 (and, in some of these embodiments, for example, the absence of defeating of the seating is an absence of extrusion of the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, through the communicator 804 of the landing seat 802).

In those embodiments where, for each one of the “N−1” downhole ones (e.g. apparatuses 200A, 200B) of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), independently, where the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, and the landing tool apparatus 800 are co-operating to establish the landed dart configuration, in some of these embodiments, for example, the landed dart configuration is sufficiently strong to withstand a pressure differential, that is established between a space, within the wellbore string passage 106, disposed uphole relative to the landed dart configuration, and a space, within the wellbore string passage 106, disposed downhole relative to the landed dart configuration (e.g. across the landed dart configuration), that exceeds the maximum pressure rating of the casing string, to which the landed dart configuration is connected, such that, while the pressure differential is being applied, there is an absence of defeating of the seating of the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, on the landing seat 802 (and, in some of these embodiments, for example, the absence of defeating of the seating is an absence of extrusion of the dart 300, that is respective to the downhole one of the “N” downhole tool apparatuses, through the communicator 804 of the landing seat 802).

Referring to FIG. 10, in some embodiments, for example, a dart activation apparatus 900 is integrated within the wellbore string 104 (e.g. via threaded connections at the uphole and downhole ends of the apparatus 900) and emplaced uphole relative to the series of “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), and, therefore, uphole relative to the furthest uphole one (e.g. apparatus 200A) of the “N” downhole tool apparatuses. The dart activation apparatus 900 includes a proximity triggering configuration 902, and the apparatus 900 is disposed uphole relative to the furthest uphole one of the “N” downhole tool apparatuses. In some embodiments, for example, the proximity triggering configuration is configured for effectuating the activation of the transitioning of the dart 300, that is respective to the furthest uphole one of the “N” downhole tool apparatuses (e.g. apparatus 200A), from the coupling-ineffective configuration, that is respective to the furthest uphole one of the “N” downhole tool apparatuses, to the coupling-effective configuration, that is respective to the furthest uphole one of the “N” downhole tool apparatuses. The dart 300, that is respective to the the furthest uphole one of the “N” downhole tool apparatuses, and the dart activation apparatus 900 are co-operatively configured such that, while the dart 300, that is respective to the furthest uphole one of the “N” downhole tool apparatuses, is being conducted downhole, through the passage 106 of the wellbore string 104, and becomes emplaced in sufficient proximity to the proximity triggering configuration 902, the proximity triggering configuration 902 activates transitioning of the dart 300, that is respective to the furthest uphole one of the “N” downhole tool apparatuses, from the coupling-ineffective configuration, that is respective to the furthest uphole one of the “N” downhole tool apparatuses, to the coupling-effective configuration, that is respective to the furthest uphole one of the “N” downhole tool apparatuses. In some embodiments, for example, the dart, that is respective to the furthest uphole one of the “N” downhole tool apparatuses, the dart activation apparatus, and the furthest uphole one of the “N” downhole tool apparatuses are co-operatively configured such that, while the dart 300, that is respective to the furthest uphole one of the “N” downhole tool apparatuses, is being conducted downhole, through the passage 106 of the wellbore string 104, after transitioning to the coupling-effective configuration, that is respective to the furthest uphole one of the “N” downhole tool apparatuses, the coupling (e.g. seating) of the dart 300, that is respective to the furthest uphole one of the “N” downhole tool apparatuses, to the furthest uphole one of the “N” downhole tool apparatuses, is established.

In some embodiments, for example, the proximity triggering configuration 902 is a field generator (such as for example, any one of, or any combination of, a magnetic field generator (e.g. one or more magnets), an electric field generator, an electromagnetic field generator, or a signal generator) for generating a dart activation field within a dart activation zone 903, for effectuating the activation of the transitioning of the dart 300, that is respective to the furthest uphole one of the “N” downhole tool apparatuses, from the coupling-ineffective configuration, that is respective to the dart 300 that is respective to the furthest uphole one of the “N” downhole tool apparatuses, to the coupling-effective configuration, that is respective to the dart 300 that is respective to the furthest uphole one of the “N” downhole tool apparatuses. In this respect, in some embodiments, for example, the dart 300, that is respective to the furthest uphole one of the “N” downhole tool apparatuses, and the dart activation apparatus 900 are co-operatively configured such that, while the dart 300, that is respective to the furthest uphole one of the “N” downhole tool apparatuses, is being conveyed downhole, in the coupling-ineffective configuration, that is respective to the dart 300 that is respective to the furthest uphole one of the “N” downhole tool apparatuses the dart 300, that is respective to the furthest uphole one of the “N” downhole tool apparatuses, becomes disposed within the generated dart activation field within the activation zone 903, and the activation of the transitioning of the dart 300, that is respective to the furthest uphole one of the “N” downhole tool apparatuses, from the coupling-ineffective configuration, that is respective to the dart 300 that is respective to the furthest uphole one of the “N” downhole tool apparatuses, to the coupling-effective configuration, that is respective to the dart 300 that is respective to the furthest uphole one of the “N” downhole tool apparatuses, is a response to the emplacement of the dart, that is respective to the furthest uphole one of the “N” downhole tool apparatuses, within the activation field that is being generated by the proximity triggering configuration 902 and disposed within the activation zone 903.

In some embodiments, for example, the transitioning of the dart 300, that is respective to the furthest uphole one of the “N” downhole tool apparatuses, with the dart activation apparatus 900, is effectuated as close as possible to the furthest uphole one of the “N” downhole tool apparatuses, while providing sufficient time for the transitioning of the dart 300 to be completed. The transitioning of the dart 300, that is respective to the furthest uphole one of the “N” downhole tool apparatuses, with the dart activation apparatus 900, as close as possible to the furthest uphole one of the “N” downhole tool apparatuses, reduces the risk that casing deformation will prevent the activated dart, that is respective to the furthest uphole one of the “N” downhole tool apparatuses, from arriving at the furthest uphole one of the “N” downhole tool apparatuses. In this respect, in some embodiments, for example, the proximity triggering configuration 902, that is respective to the dart activation apparatus 900, is spaced apart from the furthest uphole one of the “N” downhole tool apparatuses by a maximum distance of no more than 40 feet (such as, for example, no more than 35 feet, such as, for example, no more than 30 feet, such as, for example, no more than 25 feet), as measured along the central longitudinal axis of the wellbore 102. In some embodiments, for example, the proximity triggering configuration 902, that is respective to the dart activation apparatus 900, is spaced apart from the furthest uphole one of the “N” downhole tool apparatuses by a minimum distance of at least 12 feet (such as, for example, at least 15 feet) as measured along the central longitudinal axis 102A of the wellbore 102. Also, in this respect, in some embodiments, for example, the dart activation zone 903 is spaced apart from the furthest uphole one of the “N” downhole tool apparatuses by a maximum distance of no more than 40 feet (such as, for example, no more than 35 feet, such as, for example, no more than 30 feet, such as, for example, no more than 25 feet), as measured along the central longitudinal axis of the wellbore 102. In some embodiments, for example, the dart activation zone 903 is spaced apart from the furthest uphole one of the “N” downhole tool apparatuses by a minimum distance of at least 12 feet (such as, for example, at least 15 feet) as measured along the central longitudinal axis 102A of the wellbore 102. Also, in this respect, in some embodiments, for example, the dart activation zone 903.

In some embodiments, for example the dart activation apparatus 900 is separated from the furthest uphole one of the “N” downhole tool apparatuses by an intermediate wellbore string, at least a portion of which is an intermediate casing. In some embodiments, for example, the dart activation apparatus 900 is connected to the intermediate casing, such as by, for example, a threaded connection. In some embodiments, for example, the intermediate casing is a casing string. In some embodiments, for example, there is an absence of configurability of the dart activation apparatus 900 for establishing flow communication between the wellbore string passage 106 and the subterranean formation 100 (such as, for example, by opening of a flow communicator in response to displacement of a valve (e.g. sleeve), relative to the flow communicator).

Referring to FIG. 11, in some embodiments, for example, the proximity triggering configuration 902, of the dart activation apparatus 900, can be incorporated within the landing tool apparatus 800. In this respect, the proximity triggering configuration 902 (such as, for example, in the form of permanent magnets) can be incorporated within the landing seat 802 of the landing tool apparatus 800, such that, the permanent magnet is emplaced relatively close to the outside diameter of the dart 300, that is respective to the furthest uphole one of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C), while the dart, that is respective to the furthest uphole one of the “N” downhole tool apparatuses. In this respect, such emplacement of the proximity triggering configuration 902 (such as, for example, in the form of permanent magnets) improves reliability in the transitioning of the dart 300. In some embodiments, for example, the landing seat 802 is spaced apart from the furthest uphole one of the “N” downhole tool apparatuses by a maximum distance of no more than 40 feet (such as, for example, no more than 35 feet, such as, for example, no more than 30 feet, such as, for example, no more than 25 feet), as measured along the central longitudinal axis of the wellbore 102. In some embodiments, for example, the landing seat 802 is spaced apart from the furthest uphole one of the “N” downhole tool apparatuses by a minimum distance of at least 12 feet (such as, for example, at least 15 feet) as measured along the central longitudinal axis 102A of the wellbore 102. Also, in this respect, in some embodiments, for example, the dart activation zone 903.

Referring to FIGS. 1 to 7, the following describes implementation of an embodiment of a method for stimulating production of fluidic hydrocarbon-comprising material from a subterranean formation 100 and, after the stimulation, producing fluidic hydrocarbon-comprising material from the subterranean formation 100, via an embodiment of the system 5.

In some embodiments, for example, the dart 300C, that is respective to the flow communication apparatus 200C of the flow communication station 114, is pumped downhole via the wellbore string passage 106, traversing the flow communication stations 110, 112, and respective flow communication apparatuses 200A, 200 B, and becomes seated on the downhole seat 216 that is respective to the flow communication apparatus 200C (see FIG. 1). While traversing the flow communication apparatuses 200A, 200B, for each one of the flow control apparatuses 200A, 200B, independently, the respective dart 300C is conveyed through the dart-occludable communicator 218 of the downhole seat 216 that is respective to the flow communication apparatus 200A, and the dart-occludable communicator 218 of the downhole seat 216 that is respective to the flow communication apparatus 200B. After having traversed the flow communication apparatuses 200A, 200B, transitioning of the dart 300C from the coupling-ineffective configuration, that is respective to the dart 300C, to the coupling-effective configuration, that is respective to the dart 300C, by the proximity triggering configuration 220, that is respective to the apparatus 200C, is effectuated, such that the dart 300C becomes seated on the downhole seat 216, which is respective to the flow communication apparatus 200C. While the dart 300C is seated on the downhole seat 216 that is respective to the apparatus 200C, in response to application of fluid pressure force to the dart 300C in the downhole direction, the respective wellbore isolation-controlling valve configuration 404 is released from the retention (for example, by shear pins) to the respective housing 212 and the respective wellbore isolation-controlling valve configuration 404 is displaced in a downhole direction relative to the flow communicator 208 that is respective to the apparatus 200C, with effect that the opening of the flow communicator 208, that is respective to the apparatus 200C, is established. After the opening of the flow communicator 208, that is respective to the apparatus 200C, stimulating material 500 is then injected from the surface 10 to the subterranean formation via the opened flow communicator 208, which is respective to the apparatus 200C, for stimulating the zone 100C (see FIG. 2).

After the stimulation of the zone 100C, the dart 300B, that is respective to the flow communication apparatus 200B of the flow communication station 114, is pumped downhole via the wellbore string passage 106, traversing the flow communication station 110 and respective flow communication apparatus 200A, and becomes seated on the downhole seat 216, that is respective to the flow communication apparatus 200B (see FIG. 3). While traversing the flow communication apparatus 200A, the respective dart 300B is conveyed through the dart-occludable communicator 218 of the downhole seat 216 that is respective to the flow communication apparatus 200A. After having traversed the flow communication apparatus 200A, transitioning of the dart 300B from the coupling-ineffective configuration, that is respective to the dart 300B, to the coupling-effective configuration, that is respective to the dart 300B, by the proximity triggering configuration 220, that is respective to the apparatus 200B, is effectuated, such that the dart 300B becomes seated on the downhole seat 216, which is respective to the flow communication apparatus 200B. While the dart 300B is seated on the downhole seat 216 that is respective to the apparatus 200B, in response to application of fluid pressure force to the dart 300B in the downhole direction: the respective wellbore isolation-controlling valve configuration 404 is released from the retention (for example, by shear pins) to the respective housing 212 and the respective wellbore isolation-controlling valve configuration 404 is displaced in a downhole direction relative to the flow communicator 208 that is respective to the apparatus 200B, with effect that the opening of the flow communicator 208, that is respective to the apparatus 200B, is established. After the opening of the flow communicator 208, that is respective to the apparatus 200B, stimulating material 500 is then injected from the surface 10 to the subterranean formation via the opened flow communicator 208, which is respective to the apparatus 200B, for stimulating the zone 100B (see FIG. 4).

After the stimulation of the zone 100B, the dart 300A, that is respective to the flow communication apparatus 200A of the flow communication station 114, is pumped downhole via the wellbore string passage 106. Prior to reaching the downhole seat 216 of the flow communication apparatus 200A, transitioning of the dart 300A from the coupling-ineffective configuration, that is respective to the dart 300A, to the coupling-effective configuration, that is respective to the dart 300A, by the proximity triggering configuration 220, that is respective to the apparatus 200A, is effectuated, such that the dart 300 becomes seated on the downhole seat 216, which is respective to the flow communication apparatus 200A. While the dart 300A is seated on the downhole seat 216 that is respective to the apparatus 200A, in response to application of fluid pressure force to the dart 300A in the downhole direction, the respective wellbore isolation-controlling valve configuration 404 is released from the retention (for example, by shear pins) to the respective housing 212 and the respective wellbore isolation-controlling valve configuration 404 is displaced in a downhole direction relative to the flow communicator 208 that is respective to the apparatus 200A, with effect that the opening of the flow communicator 208, that is respective to the apparatus 200A, is established. After the opening of the flow communicator 208, that is respective to the apparatus 200A, stimulating material 500 is then injected from the surface 10 to the subterranean formation 100 via the opened flow communicator 208, which is respective to the apparatus 200A, for stimulating the zone 100A (see FIG. 6).

Referring to FIG. 7, after sufficient time has elapsed since the stimulation of the zone 100A, the darts 300A, 300B, 300C can be flowed back so as to create flow communication between the surface 10 and the subterranean formation 100, for enabling production 600 of reservoir fluid to the surface 10 from the subterranean formation 100 via the wellbore string passage 106. Alternatively, the flow communication can be established in response to degradation (e.g. dissolution) of the darts 300A, 300B, 300C by a degradation-promoting agent. Alternatively, the flow communication can be established by milling out the darts 300A, 300B, 300C.

In some embodiments, for example, either one of the darts 300B and 300C can become prematurely activated, with effect that the dart (300B or 300C) becomes seated on the downhole seat 216 that is respective to the apparatus 200A, which could compromise the production of reservoir fluid from the subterranean formation via the system 5.

Referring to FIG. 8, and as discussed above, in some embodiments, for example, while being deployed downhole each one of the darts 300B and 300C, independently, is disposed in an activation-disabled configuration. In some of these embodiments, for each one of the darts 300B, 300C, for example, an activation tool configuration 700 is integrated within the wellbore for actuating transitioning of the dart, that is respective to the downhole tool apparatus, from the activation-disabled configuration to the activation-enabled, coupling-ineffective configuration, within an activation zone 702 of the wellbore string passage 106, such that the dart becomes ready for activation only after the dart becomes emplaced within the activation zone 702.

Referring to FIG. 9, and as discussed above, in some embodiments, for example, while being deployed downhole, each one of the darts 300B and 300C could become prematurely activated (e.g. expanded), and the landing tool apparatus 800 provides for seating of the prematurely activated darts, before their unintentional seating, in downhole flow control apparatuses (e.g. apparatus 300A), is established.

Referring to FIG. 10, and as discussed above, the dart activation apparatus 900 includes a proximity triggering configuration 902 for activating the dart 300 for enabling seating of the dart in the furthest uphole one 200A of the downhole flow control apparatuses (200A, 200B, 200C).

The preceding discussion provides many example embodiments. Although each embodiment represents a single combination of inventive elements, other examples may include all suitable combinations of the disclosed elements. Thus if one embodiment comprises elements A, B, and C, and a second embodiment comprises elements B and D, other remaining combinations of A, B, C, or D, may also be used.

Although the embodiments have been described in detail, it should be understood that various changes, substitutions and alterations could be made herein.

Moreover, the scope of the present application is not intended to be limited to the particular embodiments of the process, machine, manufacture, and composition of matter, means, methods and steps described in the specification. As one of ordinary skill in the art will readily appreciate from the disclosure of the present invention, processes, machines, manufacture, compositions of matter, means, methods, or steps, presently existing or later to be developed, that perform substantially the same function or achieve substantially the same result as the corresponding embodiments described herein may be utilized. Accordingly, the appended claims are intended to include within their scope such processes, machines, manufacture, compositions of matter, means, methods, or steps.

As can be understood, the examples described above and illustrated are intended to be examples only. The invention is defined by the appended claims.