SYSTEMS AND METHODS FOR STIMULATING HYDROCARBON PRODUCTION FROM A SUBTERRANEAN FORMATION

Description

FIELD

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

BACKGROUND

Hydrocarbon production from a subterranean formation is typically effectuated via a wellbore. Flow communication, between the hydrocarbon material, within the subterranean formation, and the wellbore is often obtained by perforating the subterranean formation from within the wellbore (such as with a perforating gun that is deployed within the wellbore via wireline), and then injecting treatment material into the subterranean formation via the perforations. The perforations are typically fluidically isolated so that the treatment material is directed into the subterranean formation.

SUMMARY

In one aspect there is provided a method of completing a wellbore comprising: establishing a perforation interval, within a wellbore, for establishing flow communication between the wellbore and a subterranean formation; after the establishing of the perforated interval within the wellbores, deploying an untethered dart, into the wellbore, with effect that the untethered dart becomes seated against a seat disposed within the wellbore for establishing the wellbore isolation-controlling valve configuration; and after the establishment of the wellbore isolation-controlling valve configuration within the wellbore, injecting treatment material into the wellbore with effect that the treatment material is injected into the subterranean formation via the perforated interval; wherein: a time interval, from the establishing of the perforated interval within the wellbore to the establishing of the wellbore isolation-controlling valve configuration, has a value that is at least six (6) hours

In another aspect, there is provided a wellbore completion comprising a wellbore string that is emplaced within a wellbore, wherein the wellbore string includes a plurality of flow communication stations. axially spaced from each other along the wellbore such that each one of the flow communication stations, independently, is positioned adjacent a respective zone of the subterranean formation, each one of the one or more flow communication stations includes a respective downhole tool apparatus, such that a plurality of downhole tool apparatuses is defined, for each one of the flow communication stations, independently, and for each one of the respective downhole tool apparatuses, the downhole tool, that is respective to the downhole tool apparatus, includes a respective seat, for each one of the downhole tool apparatuses, independently, a respective dart is configured for coupling to the seat that is respective to the downhole tool apparatus that is respective to the flow communication station, such that while the dart, that is respective to the downhole tool apparatus, is seated on the downhole seat, that is respective to the downhole tool apparatus, a seated dart configuration, that is respective to the downhole tool apparatus, is obtained, and each one of the darts, that is respective to a downhole tool apparatus that is disposed downhole relative to the seat, that is respective to the flow communication station positioned adjacent to a respective zone, of the subterranean formation, that includes the hydraulic fracturing-resistant portion, is configured to co-operate with the seat, that is respective to the flow communication station positioned adjacent to a respective zone, of the subterranean formation, that includes the hydraulic fracturing-resistant portion such that, for each one of the darts, independently, while the dart is traversing the seat, that is respective to the flow communication station positioned adjacent to a respective zone, of the subterranean formation, that includes a hydraulic fracturing-resistant portion, there is an absence of seating of the dart on the seat.

BRIEF DESCRIPTION OF DRAWINGS

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

FIGS. 1 to 9 are schematic illustrations depicting implementation of an embodiment of a method for completing a well for producing hydrocarbon-comprising material from a subterranean formation, via an embodiment of the system of the present disclosure; and

FIGS. 10 to 14 are schematic illustrations depicting a method for completing a pair of wells, disposed on the same well pad, for creating a system for stimulating production of hydrocarbon-comprising material from a subterranean formation.

DETAILED DESCRIPTION

The present disclosure provides apparatuses and systems that can be used in well completion for enabling selective flow communication between the surface 10 and a subterranean formation 100.

Referring to FIGS. 1 to 9, there is provided a wellbore material transfer system 5 for conducting (e.g. flowing) material between the surface 10 and the subterranean formation 100. In some embodiments, for example, the subterranean formation 100 is a hydrocarbon material-containing reservoir. In some embodiments, for example, the conducting is effectuated via one or more wellbores 102.

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 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, fluid, that is 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 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.

In some embodiments, for example, the wellbore string 104 includes a plurality of flow communication stations. In some embodiments, for example, successive flow communication stations 110, 112, 114, 116 are axially spaced from each other along the wellbore 102. In some embodiments, for example, the spacing is such that each one of the flow communication stations 110, 112, 114, 116, independently, is positioned adjacent a respective zone (or interval) 100A, 100B, 100C, 100D of the subterranean formation 100. In some embodiments, for example, the plurality of flow communication stations 110, 112, 114,116, is defined by a series of flow communication stations 110, 112, 114, 116 that are spaced along a longitudinal axis of the wellbore 102

Each one of the one or more flow communication stations 110, 112, 114, 116 includes a respective downhole tool apparatuses 200, such that a plurality of downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C, 200D) 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, 200D), independently, includes a respective downhole tool apparatus housing 212 that is integrated within the wellbore string 104 and also includes a respective downhole tool. In some embodiments, for example, for each one of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C, 200D), 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, 200D), 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.

For each one of the flow communication stations 110, 112, 114, 116, independently, and for each one of the respective downhole tool apparatuses 200A, 200B, 200C, 200D, the downhole tool, that is respective to the downhole tool apparatus, includes a respective seat 204. For each one of the downhole tool apparatuses 200A, 200B, 200C, 200D, independently, a respective dart 300 is configured for coupling to (e.g. seating on) the seat that is respective to the downhole tool apparatus that is respective to the flow communication station, such that while the dart 300, that is respective to the downhole tool apparatus, is seated on the downhole seat 204, that is respective to the downhole tool apparatus, a seated dart configuration 400, 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 204, 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 204, that is respective to the downhole tool apparatus.

In some embodiments, for example, for each one of the flow communication stations 110, 112, 114, 116, independently, and for each one of the respective downhole tool apparatuses 200A, 200B, 200C, 200D, the seat 204, that is respective to the downhole tool apparatus, is defined by the wellbore string 104, such that the wellbore string defines a plurality of seats. In some embodiments, for example, the plurality of seats are integrated (e.g. installed) with (e.g. along) the wellbore string 104 prior to the wellbore string being run into the wellbore 102.

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, the dart 300 is a ball.

In some embodiments, for example, for each one of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C, 200D), independently, a respective dart-occludable communicator 218 (e.g. an orifice) extends through the downhole seat 204, 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, 200D), independently, the dart 300, that is respective to the downhole tool apparatus, the downhole seat 204, 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 204, 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, 200D), independently, the dart 300, that is respective to the downhole tool apparatus, the downhole seat 204, 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 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, 200D), independently, the dart 300, that is respective to the downhole tool apparatus, the downhole seat 204, 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 (see FIG. 9).

In those embodiments where, for each one of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C, 200D), independently, the dart 300, that is respective to the downhole tool apparatus, the downhole seat 204, 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, 200D), 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, 200D) 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, 200D), 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. 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, 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 204 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), such that 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 apparatus, and (ii) 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 embodiments, for example, for each one of the “N−1” downhole one(s) of the “N” downhole tool apparatuses (e.g. apparatuses 200B, 200C, 200D), 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, 200D), 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, 200D), 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 204 of the downhole tool 214, that is respective to the downhole tool apparatus), such that the coupled dart configuration (e.g. the seated 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 seat 204 of 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 204, 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 (e.g. apparatuses 200B, 200C, 200D) of the “N” downhole tool apparatuses (e.g. apparatuses 200A, 200B, 200C, 200D), 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 218 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 218, that is respective to the downhole tool apparatus, and the flow communicator 218 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, 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 seat 204, 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 204 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 seat 204, 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 (e.g. seating of the dart 300, that is respective to the downhole tool apparatus, on the seat 204 that is respective to the downhole tool apparatus); 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 seating on the seat 204 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, 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 is programmable for co-operation with 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.

In some embodiments, for example, for each one of the “N” downhole tool apparatuses, 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, and the dart 300, that is respective to the furthest uphole one of the “N” downhole tool apparatuses (e.g. apparatuses 200A), 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 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 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. As with some of the embodiments described above, in some of these embodiments, for example, for each one of the “N−1” downhole ones of the downhole tool apparatuses (e.g. apparatuses 200B, 200C, 200D), independently, the field generator 220, 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. With respect to the furthest uphole one of the “N” downhole tool apparatuses, the field generator 220, that is respective to the furthest uphole one of the “N” downhole tool apparatuses, is disposed in a standalone apparatus 221 that is disposed uphole relative to the furthest uphole one of the “N” downhole tool apparatuses.

Each one of the flow communication stations 110, 112, 114, 116, independently, is configurable in a flow communication-ineffective state and a flow communication-effective state. For each one of the flow communication stations 110, 112, 114, 116, independently, in the flow communication-ineffective state, there is an absence of flow communication between the flow communication station and the respective zone, and in the flow communication-effective state, flow communication is established between the flow communication and the respective zone. In some embodiments, for example, for each one of the flow communication stations 110, 112, 114, 116, independently, the flow communication-effective state is established by respective perforations extending through the wellbore string 104 (such as, for example, the casing 105, including cemented casing 105) defined within a respective perforated interval 1141 of the wellbore string 104, such as, for example, perforations created by explosive charges, such as, for example, via a perforating gun that is deployed into the wellbore 102 via wireline. In some embodiments, for example, for each one of the flow communication stations 110, 112, 114, 116, independently, while the flow communication station is disposed in the flow communication-effective state, the perforated interval 1141, that is respective to the flow communication station, is disposed uphole relative to the seat 204, that is respective to the flow communication station, and, in some embodiments, for example, is also disposed downhole relative to the seat 204, that is respect to an adjacent uphole one, of the flow communication stations, disposed immediately uphole relative to the flow communication station.

In operation, the perforated interval 1141, that is respective to the furthest downhole one of the flow communication stations (e.g. station 116), is established, such as, for example via a perforating gun that is deployed within the wellbore 102 via wireline (see FIG. 2). After the establishing of the perforated interval 1141 that is respective to the furthest downhole one of the flow communication stations (e.g. station 116), the dart 300, that is respective to the furthest downhole one of the flow communication stations (station 116), is conducted (such as, for example, is conducted downhole by fluid flow (such as, for example, “pumped down”) to the furthest downhole one of the flow communication stations (station 116), such as, for example, via deployment from the surface 10). While being conducted downhole, the dart 300, that is respective to the furthest downhole one of the flow communication stations (e.g. station 116), traverses, in sequence, the flow communication stations 110, 112, 114. While traversing the flow communication station 114, the dart 300, that is respective to the furthest downhole one of the flow communication stations (e.g. station 116), becomes disposed within sufficient proximity of the proximity triggering configuration (e.g. field generator) of the downhole tool apparatus 200C that respective to the flow communication station 116, with effect that the dart 300, that is respective to the furthest downhole one of the apparatuses (apparatus 200D), transitions from the coupling-ineffective configuration, that is respective to the dart 300, that is respective to the furthest downhole one of the apparatuses (e.g. apparatus 200D), to the coupling-effective configuration, that is respective to the dart 300 that is respective to the furthest downhole one of the apparatuses (e.g. apparatus 200D). In this respect, after traversing the flow communication station 110, the dart 300, that is respective to the furthest downhole one of the apparatuses (e.g. apparatus 200D) is disposed in the coupling-effective configuration, and continues to be conducted downhole to the flow communication stations 116, with effect that the dart 300, that is respective to the furthest downhole one of the apparatuses (e.g. apparatus 200D), becomes coupled to (e.g. seated on) the seat 204, that is respective to the downhole apparatus 200D that is respective to the flow communication station 116, with effect that the seated dart configuration, that is respective to the furthest downhole one of the flow communication stations (station 116), is established (see FIG. 3). After the establishing of the seated dart configuration that is respective to the furthest downhole one of the flow communication stations (or, in some embodiments, for example, in parallel with the pumping down of the dart 300), the treatment material is injected into the subterranean formation via the perforated interval 1141 that is respective to the furthest downhole one (station 116) of the flow communication stations. In some embodiments, for example, the injecting of the treatment material is over a time interval of at least five minutes, such as, for example, at least ten (10) minutes, such as, for example, at least 30 minutes, such as, for example, at least one hour, such as, for example, at least 24 hours. After completion of the injecting via the flow communication station 116, perforating, dart deployment, and treatment material injection, as described above is effectuated for the remaining uphole-disposed flow communication stations (110, 112, 1114), in succession (see FIG. 4 to 9). In some embodiments, for example, the time interval between establishing of the perforated interval 1141 and commencement of the pumping down of the darts is at least one (1) hour, such as, for example, at least two (2) hours, such as, for example, at least four (4) hours, such as, for example, at least six (6) hours, such as, for example, at least 12 hours, such as, for example, at least 24 hours.

In some embodiments, for example, rather than effectuating perforating, dart deployment, and treatment material injection for all of the flow communication stations (e.g. 110, 112, 114, 116), some of the flow communication stations are skipped (i.e. there is an absence of perforating, dart deployment, and treatment material injection for such flow communication stations. In this respect, in some embodiments, for example, during drilling of the wellbore, it may be determined that properties of a hydraulic fracturing-resistant portion of the subterranean formation (such as, for example, in one or more of the zones 100A, 100B, 100C, 100D) are such that hydraulic fracturing of such portion of the subterranean formation is not economical (e.g. the subterranean formation includes hard rock). Because the plurality of seats, defined by the wellbore string are integrated (e.g. installed) with (e.g. along) the wellbore string 104 prior to the drilling of the wellbore, it is, in some embodiments, desirable to negotiate around the seat which corresponds to hydraulic fracturing-resistant portion of the subterranean formation, such that none of the darts 300 of the system 5 become seated on the seat 204. In such case, in those embodiments of the system 5 where the subterranean formation includes a hydraulic fracturing-resistant portion, each one of the darts 300, that is respective to a downhole tool apparatus that is disposed downhole relative to the seat 200, that is respective to the flow communication station positioned adjacent to a respective zone, of the subterranean formation 100, that includes the hydraulic fracturing-resistant portion, is configured to co-operate with the seat 200, that is respective to the flow communication station positioned adjacent to a respective zone, of the subterranean formation 100, that includes the hydraulic fracturing-resistant portion such that, for each one of the darts 300, independently, while the dart 300 is traversing the seat 204, that is respective to the flow communication station positioned adjacent to a respective zone, of the subterranean formation 100, that includes the hydraulic fracturing-resistant portion, there is an absence of seating of the dart 300 on the seat 204. For example, where the zone 100B, that is positioned adjacent to the flow communication station 110B, includes the hydraulic fracturing-resistant portion, for each one of the darts 300, that is respective to a the apparatuses 200A (disposed downhole relative to the zone 100B), while the dart 300 is traversing the seat 204, that is respective to the flow communication station 110B, there is an absence of seating of the dart 300 on the seat 204 (for example, the dart ignores the generated transitioning-effective field), that is respective to the flow communication station 110B, such that the dart becomes disposed downhole relative to the flow communication station 110B.

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, 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 204 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), such that 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 apparatus, and (ii) 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)

Referring to FIGS. 10 to 14, in some embodiments, for example, the conducting is effectuated via a plurality of wellbores 102, 102X, each of which is configured as described above. In some of these embodiments, for example, the plurality of wellbores are emplaced within a multi-well pad that has been established by pad drilling. In some embodiments, for example, the same pumping unit is used for pumping down the darts for all of the plurality of wellbores (and/or, in some embodiments, for example, also for the injection of treatment material into all of the plurality of wellbores).

In this respect, referring to FIG. 11, a perforated interval 1141 is established within a first one 102 of the wellbores, such as, for example, with a perforating gun that has been deployed downhole with a wireline unit. In some embodiments, for example, the perforated interval includes one or more perforations. Referring to FIG. 12, after the establishing of the perforated interval 1141 within the first one 102 of the wellbores, the untethered dart is pumped down for establishing the wellbore isolation-controlling valve configuration 404 (downhole relative to the perforated interval 1141) within the first one 102 of the wellbores. In some embodiments, for example, the time interval, from the establishing of the perforated interval 1141 within the first one 102 of the wellbores to the establishing of the wellbore isolation-controlling valve configuration 404. Referring to FIG. 13, after the establishment of the wellbore isolation-controlling valve configuration 404 within the first one of the wellbores, the treatment material is then injected into the first one of the wellbores and into the subterranean formation via the perforated interval 1141, with a pumping unit. In some embodiments, for example, the treatment material is continuously injected for a time interval of greater than three (3) hours, such as, for example, greater than four (4) hours, and over the time interval, the continuous injecting of the treatment material is with effect that pressure is applied to the wellbore isolation-controlling valve configuration 404, and the applied pressure has a value that is greater than a lower limit that is greater than 5,000 psi (such as, for example, greater than 6,000 psi, such as, for example, greater than 7,000 psi, such as, for example, greater than 8,000 psi, such as, for example, greater than 9,000 psi) and, in some embodiments, the applied pressure has a value that is greater than the lower limit and no more than 10,000 psi. Over the time interval, the wellbore isolation-controlling valve configuration 404 continues to hold drip tight.

In some embodiments, for example, the untethered dart is pumped down via the pumping unit that is motivating the injection of the treatment material. In some embodiments, for example, the time interval, from the establishing of the perforated interval 1141 within the second one 102X of the wellbores to the injecting of the treatment material, is at least is at least six (6) hours, such as, for example, at least 12 hours, such as, for example, at least 18 hours, such as, for example, at least 24 hours In some embodiments, for example, the time interval from the establishment of the wellbore isolation-controlling valve configuration 404, within the first one of the wellbores, to the injection of the treatment material is less than one (1) hour, such as, for example, less than 30 minutes, such as, for example, less than five (5) minutes, such as, for example, less than two (2) minutes.

Also after the establishing of the perforated interval 1141 within the first one of the wellbores, a perforated interval 1141 is established within a second one 102X of the wellbores, such as, for example, with a perforating gun that has been deployed downhole with a wireline unit, In some embodiments, for example, the perforated interval 1141 is established within the second one 102X of the wellbores with the same perforating gun as that which has established the perforated interval 1141 within the first one 102 of the wellbores (see FIG. 14). In some embodiments, for example, the perforated interval 1141 is established within the second one 102X of the wellbores while the pumping unit is being used for injecting the treatment material into the subterranean formation via the first one 102 of the wellbores. After the perforated interval 1141 has been established in the second one 102X of the wellbores, the untethered dart is pumped down for establishing the wellbore isolation-controlling valve configuration 404 (downhole relative to the perforated interval 1141) within the second one 102X of the wellbores. In some embodiments, for example, the time interval, from the establishing of the perforated interval 1141 within the second one 102X of the wellbores to the establishing of the wellbore isolation-controlling valve configuration 404, is at least six (6) hours, such as, for example, at least 12 hours, such as, for example, at least 18 hours, such as, for example, at least 24 hours. After the establishment of the wellbore isolation-controlling valve configuration 404 within the second one 102X of the wellbores, the treatment material is then injected into the second one 102X of the wellbores and into the subterranean formation via the perforated interval 1141, with a pumping unit. In some embodiments, for example, the untethered dart is pumped down via the pumping unit that is motivating the injection of the treatment material. In some embodiments, for example, the time interval, from the establishing of the perforated interval 1141 within the second one 102X of the wellbores to the injecting of the treatment material, is at least is at least six (6) hours, such as, for example, at least 12 hours, such as, for example, at least 18 hours, such as, for example, at least 24 hours. In some embodiments, for example, the time interval from the establishment of the wellbore isolation-controlling valve configuration 404, within the second one 102X of the wellbores, to the injection of the treatment material is less than one (1) hour, such as, for example, less than 30 minutes, such as, for example, less than five (5) minutes, such as, for example, less than two (2) minutes.

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.