Electronic initiator sleeves and methods of use

Apparatuses, systems, and methods for performing wellbore completion and production operations in a subterranean formation are provided. In some embodiments, the methods include: disposing an electronic initiator sleeve within a closed wellbore penetrating at least a portion of a subterranean formation, wherein the electronic initiator sleeve comprises: a housing having at least one port, a sleeve in a closed position, an actuator, and at least one sensor; increasing fluid pressure within the closed wellbore for a period of time, wherein the sleeve remains in the closed position during the period of time; detecting a signal with the at least one sensor; and actuating the actuator in response to the signal to transition the sleeve from the closed position to an open position.

CROSS-REFERENCE TO RELATED APPLICATION

The present application is a U.S. National Stage Application of International Application No. PCT/US2017/064931 filed Dec. 6, 2017, which is incorporated herein by reference in its entirety for all purposes.

BACKGROUND

Hydrocarbons, such as oil and gas, are commonly obtained from subterranean formations that may be located onshore or offshore. The development of subterranean operations and the processes involved in removing hydrocarbons from a subterranean formation may involve a number of different steps such as, for example, drilling a wellbore at a desired well site, treating the wellbore to optimize production of hydrocarbons, and performing the necessary steps to produce and process the hydrocarbons from the subterranean formation.

After a wellbore has been formed, various downhole tools may be inserted into the wellbore to extract the natural resources such as hydrocarbons or water from the wellbore, to inject fluids into the wellbore, and/or to maintain the wellbore. It is common practice in completing oil and gas wells to set a string of pipe, known as a casing string, in the wellbore and to cement around the outside of the casing to isolate the various formations penetrated by the well. The casing string may include various wellbore tools.

After cementing of the casing is complete, the bottom of the wellbore must be re-opened to establish fluid communication between the hydrocarbon-bearing formations and the interior of the casing. It often may be desirable to test the integrity of the casing prior to re-opening the wellbore. The casing integrity testing and the re-opening of the wellbore may be done with a wellbore tool commonly referred to as a “toe sleeve” or “initiator sleeve,” which is commonly located at the toe of the casing string.

While embodiments of this disclosure have been depicted, such embodiments do not imply a limitation on the disclosure, and no such limitation should be inferred. The subject matter disclosed is capable of considerable modification, alteration, and equivalents in form and function, as will occur to those skilled in the pertinent art and having the benefit of this disclosure. The depicted and described embodiments of this disclosure are examples only, and not exhaustive of the scope of the disclosure.

DESCRIPTION OF CERTAIN EMBODIMENTS

The present disclosure relates to apparatuses, systems, and methods for performing wellbore completion and production operations in a subterranean formation. More particularly, the present disclosure relates to electronic initiator sleeves and systems for initiating fluid flow from closed wellbores into subterranean formations using signals.

The present disclosure provides one or more electronic initiator sleeves comprising a housing having at least one port, a sleeve disposed within the housing, an actuator disposed within the housing, and a sensor coupled to the housing. The electronic initiator sleeves may be disposed within a closed wellbore penetrating at least a portion of a subterranean formation. The electronic initiator sleeves may be incorporated within a tubular string disposed within the closed wellbore. The sleeve of the electronic initiator sleeve may be configured to transition from a closed position to an open position to establish a route of fluid communication between the closed wellbore and the subterranean formation. In certain embodiments, the sleeve may remain in the closed position during the performance of a casing integrity test to prevent fluid flow from the closed wellbore to the subterranean formation. In certain embodiments, the sensor of the electronic initiator sleeve may detect a signal and the actuator of the electronic initiator sleeve may actuate in response to the signal to transition the sleeve from the closed position to the open position and initiate fluid flow from the closed wellbore to the subterranean formation.

Among the many potential advantages to the apparatuses, systems, and methods of the present disclosure, only some of which are alluded to herein, the apparatuses, systems, and methods of the present disclosure may facilitate the performance of casing integrity testing with minimal risk of exceeding test pressure or inadvertently opening the initiator sleeve. In certain embodiments, the systems, apparatuses, and methods of the present disclosure may provide the ability to stop and resume casing integrity testing with no time limit, which may allow for remedial cementing operation to be completed, if necessary. In certain embodiments, the apparatuses, systems, and methods of the present disclosure may also facilitate interventionless means to create a flow path at the toe of a wellbore penetrating a subterranean formation.

Embodiments of the present disclosure and its advantages may be understood by referring toFIGS. 1 through 3, where like numbers are used to indicate like and corresponding parts.FIGS. 1A and 1Bdepict an electronic initiator sleeve100in accordance with certain embodiments of the present disclosure.FIG. 1Adepicts electronic initiator sleeve100in a closed position whileFIG. 1Bdepicts electronic initiator sleeve100in an open position. Electronic initiator sleeve100may comprise a housing102having at least one port104, a sleeve106, an actuator108, and a sensor110. Actuator108may comprise any suitable actuator including, but not limited to, an electromagnetic device (e.g., a motor, gearbox, or linear screw), a solenoid actuator, a piezoelectric actuator, a hydraulic pump, a chemically activated actuator, a heat activated actuator, a pressure activated actuator, or any combination thereof. In certain embodiments, for example, actuator108may be a linear actuator that retracts or extends a pin for permitting or restricting movement of a component of electronic initiator sleeve100. Sensor110may comprise any suitable sensor including, but not limited to, a pressure sensor, a temperature sensor, a pH sensor, a flow sensor, a hydrophone, a vibrational sensor, an acoustic sensor, an accelerometer, a piezoelectric sensor, a strain gauge, or any combination thereof.

In certain embodiments, electronic initiator sleeve100may also comprise on-board electronics112which may include, for example, a controller, a processor, memory, or any combination thereof. Actuator108, on-board electronics112, or both may be supplied with electrical power via an on-board battery, a downhole generator, or any other electrical power source. In certain embodiments, one or more of the actuator108, sensor110, and on-board electronics112may be fully disposed within housing102. In other embodiments, one or more of the actuator108, sensor110, and on-board electronics112may be partially disposed within housing102. In yet other embodiments, one or more of the actuator108, sensor110, and on-board electronics112may be positioned on, about, or external to housing102.

Sensor110may detect a signal. In certain embodiments, the signal may be generated by adjusting one or more conditions within a closed wellbore including, but not limited to, the pressure, the temperature, the pH, the flow rate, the acoustic vibration, the magnetic field, and the electromagnetic field. In certain embodiments, the signal may comprise a pulse width modulated signal, a signal varying threshold values, a ramping signal, a sine waveform signal, a square waveform signal, a triangle waveform signal, a sawtooth waveform signal, the like, or combinations thereof. Further, the waveform may exhibit any suitable duty-cycle, frequency, amplitude, duration, or combinations thereof. In certain embodiments, the signal may comprise a sequence of one or more predetermined threshold values, a predetermined discrete threshold value, a predetermined series of ramping signals, a predetermined pulse width modulated signal, any other suitable waveform as would be appreciated by one of skill in the art, or combinations thereof. Although signals are discussed herein, a person of ordinary skill in the art with the benefit of this disclosure will appreciate that the one or more signals may be wired signals, wireless signals, or both.

In certain embodiments, sensor110may convert the signal into an electrical signal. In certain embodiments, on-board electronics112may receive one or more electrical signals from sensor110based on the signal. On-board electronics112(e.g., a controller) may execute instructions based, at least in part, on the electrical signal. One or more of the instructions executed by on-board electronics112may cause on-board electronics112(e.g., a processor) to send one or more signals to actuator108thereby causing actuator108to actuate. Thus, in certain embodiments, actuator108may actuate based, at least in part, on the signal detected by sensor110.

In certain embodiments, on-board electronics112may communicate with sensor110, actuator108, or both directly or indirectly, wired or wirelessly. For example, in one or more embodiments on-board electronics112may communicate via one or more wires including, but not limited to, solid core copper wires, insulated stranded copper wires, unshielded twisted pairs, fiber optic cables, coaxial cables, any other suitable wires as would be appreciated by one of skill in the art, or combinations thereof. In certain embodiments, on-board electronics112may communicate with sensor110, actuator108, or both via one or more signaling protocols including, but not limited to, an encoded digital signal.

In certain embodiments, sensor110may be configured to detect a predetermined wireless signal and to communicate a corresponding electrical signal to on-board electronics112. In one or more embodiments, the predetermined signal may comprise or be indicative of one or more predetermined threshold values, a predetermined discrete threshold value, a predetermined series of ramping signals, a predetermined pulse width modulated signal, or any combination thereof. On-board electronics112may instruct actuator108to actuate based, at least in part, on the electrical signal received from sensor110. In certain embodiments, on-board electronics112may send an actuation signal corresponding to the electrical signal received from sensor110to actuator108instructing actuator108to actuate.

For instance, in one embodiment, sensor110may detect a predetermined signal in the form of a rise in hydrostatic pressure from an original pressure (for example, an original pressure of about 100 pounds per square inch (psi) (approximately 689.48 kiloPascal (kPa)) to one or more first measured pressures (for example, one or more first measured pressures between about 200 psi (approximately 1378.95 kPa) and about 400 psi (approximately 2757.9 kPa) for a first time period t1(for example, t1may be a time period of about 8 to 10 minutes, or any other range of time period) followed by a rise to one or more second measured pressures (for example, one or more second measured pressures between about 600 psi (approximately 4136.85 kPa) and about 800 psi (approximately 4136.85 kPa)) for a second time period t2(for example, t2may be a second time period of about 8 to 10 minutes, or any other range of time) and then a return to the original pressure. Once the predetermined signal is detected, sensor110may send a corresponding electrical signal to on-board electronics112, which may in turn send a corresponding actuation signal to actuator108instructing actuator108to actuate.

In certain embodiments, there may be a time delay between receipt of the predetermined signal by sensor110and communication of a corresponding electrical signal to on-board electronics112. In certain embodiments, there may be a time delay between receipt of the electrical signal by on-board electronics112and communication of a corresponding actuation signal to actuator108. Thus, in certain embodiments, there may be a time delay between detection of the predetermined signal by sensor110and actuation of actuator108. For instance, sensor110may detect the predetermined signal and promptly communicate a corresponding electrical signal to on-board electronics112, and on-board electronics112may wait a time period (or time delay) before sending a corresponding actuation signal to actuator108. In such embodiments, receipt of the electrical signal by on-board electronics112may initiate a timer, and the corresponding actuation signal may be sent to actuator108upon expiration of the timer. One of skill in the art with the benefit this disclosure will recognize the appropriate length of the time delay.

FIGS. 2A-Dgraphically depict examples of predetermined signals in accordance with certain embodiments of the present disclosure. The predetermined signals inFIGS. 2A-Dare merely illustrative and do not limit the appropriate types of predetermined signals. Furthermore, although the predetermined signals inFIGS. 2A-Dare depicted using pressure signals, any suitable predetermined signal may be used in the electronic initiator sleeves of the present disclosure, including, but not limited to temperature signals, pH signals, flow rate signals, acoustic vibration signals, magnetic field signals, and electromagnetic field signals, or combinations thereof. In one or more embodiments, the predetermined signals may be wired or wireless signals.

FIG. 2Adepicts a predetermined signal based on a series of pressure pulses. For predetermined signals based on pulses, the on-board electronics112may be configured to execute instructions in response to different quantities or patterns of pulses. For example, on-board electronics112may respond to a total quantity of pulses, a specific number of pulses within a period of time, a delay between pulses, a specific pattern of pulses and delays, or any similar signal. AlthoughFIG. 2Adepicts a binary predetermined signal of low and high values, the predetermined signal could be non-binary.

FIG. 2Bdepicts a predetermined signal based on a pressure exceeding a threshold value. For predetermined signals based on a threshold value of a wellbore condition (e.g., pressure), on-board electronics112may be configured to execute instructions in response to being above a threshold value, being within a range of values, remaining under a threshold value, or crossing a threshold value a certain number of times.

FIG. 2Cdepicts a predetermined signal based on the duration or dwell time of one or more pressures. For predetermined signals based on duration or dwell time of a wellbore condition (e.g., pressure), the on-board electronics112may be configured to execute instructions in response to the wellbore condition being at, above, or below a particular value for a particular period of time, or in response to the absence of the wellbore condition for a particular period of time or both.

FIG. 2Ddepicts a predetermined signal based on increases and decreases in pressure. For predetermined signals based on increases and/or decreases of a wellbore condition (e.g., pressure), the on-board electronics112may be configured to execute instructions in response to, for example, a specific pattern of the wellbore condition over time, the amount of change in the wellbore condition, the duration over which the wellbore condition remains changed, or whether the wellbore condition increased, decreased, or both more than a threshold value. The increase and/or decrease of the wellbore condition may be independent of the absolute magnitude of the increase or decrease, so long as the increase or decrease in wellbore condition is above a threshold amount.

In certain embodiments, actuator108may actuate to move one or more components of electronic initiator sleeve100in response to the output from on-board electronics112to transition sleeve106from a closed position (FIG. 1A) to an open position (FIG. 1B). In certain embodiments, as shown inFIG. 1A, electronic initiator sleeve100may comprise a hydraulic chamber116comprising oil and an electro-hydraulic lock that comprises, for instance, a rupture disk114and a piercing mechanism117. In such embodiments, the electro-hydraulic lock may hold sleeve106in the closed position under the electro-hydraulic lock is removed. In such embodiments, the electro-hydraulic lock may be removed by actuator108moving piercing mechanism117in response to the output from on-board electronics112based on the predetermined signal detected by sensor110thereby causing it to break (e.g., rupture, puncture, and/or perforate) rupture disk114, as shown inFIG. 1B. The oil may evacuate hydraulic chamber116upon the breaking of rupture disk114creating a pressure imbalance that causes sleeve106to transition from the closed position to the open position. Alternatively, in certain embodiments, electronic initiator sleeve100may comprise a valve connected to hydraulic chamber116that holds sleeve106the closed position while the valve is closed. In such embodiments, actuator108may open the valve in response to the output from on-board electronics112based on the predetermined signal detected by sensor110thereby causing the oil to evacuate hydraulic chamber116. A pressure imbalance may result causing sleeve106to transition from the closed position to the open position.

In other embodiments, electronic initiator sleeve100may comprise a compressed spring connected to sleeve106and actuator108that holds sleeve106in the closed position when compressed. In such embodiments, actuator108may release the compressed spring in response to the output from on-board electronics112based on the predetermined signal detected by sensor110thereby causing sleeve106to transition from a closed position to an open position. In other embodiments, electronic initiator sleeve100may comprise a baffle connected to sleeve106, and actuator108may be coupled to a valve. In such embodiments, actuator108may open the value in response to the output from on-board electronics112based on the predetermined signal detected by sensor110causing a ball to be released down the closed wellbore. The ball may contact the baffle thereby causing sleeve106to transition from a closed position to an open position.

In other embodiments, sleeve106and actuator108may be coupled to one or more motors. In such embodiments, actuator108drive the one or more motors in response to the output from on-board electronics112based on the predetermined signal detected by sensor110thereby causing sleeve106to transition from a closed position to an open position. In other embodiments, sleeve106and actuator108may be coupled to one or more pumps. In such embodiments, actuator108drive the one or more pump in response to the output from on-board electronics112based on the predetermined signal detected by sensor110thereby causing a fluid to be pumped into the closed wellbore. The fluid may cause the sleeve106to transition from a closed position to an open position. The electronic initiator sleeves, systems, and methods of the present disclosure may utilize any combination of the foregoing embodiments to transition sleeve106from the closed position to the open position.

In certain embodiments, as shown inFIG. 1A, electronic initiator sleeve100may also comprise one or more shear pins118. In such embodiments, shear pins118may shear or break once the pressure inside electronic initiator sleeve100reaches a predetermined pressure. The combination of shear pins118with actuator108may prevent sleeve106from prematurely transitioning from the closed position to the open position. For instance, in one embodiment, electronic initiator sleeve100may comprise one or more shear pins118and a hydroelectric lock as described above. In such embodiment, the hydroelectric lock may be removed as described above permitting sleeve106to transition from the closed position to the open position. However, shear pins118may prevent sleeve106from transition to the open position until the pressure inside electronic initiator sleeve100reaches a predetermined pressure that is sufficient to shear or break shear pins118.

FIG. 3is a schematic of a well system300following a multiple-zone completion operation. A wellbore328extends from a surface332and through a subterranean formation326. The wellbore328has a substantially vertical section304and a substantially horizontal section306, vertical section304and horizontal section306being connected by a bend308. Horizontal section306extends through a hydrocarbon bearing subterranean formation326. One or more casing strings310are inserted and cemented into the wellbore328to prevent fluids from entering the wellbore. Fluids may comprise any one or more of formation fluids (such as production fluids or hydrocarbons), water, mud, fracturing fluids, or any other type of fluid that may be injected into or received from subterranean formation326.

Although the wellbore328shown inFIG. 1includes vertical section304and horizontal section306, the wellbore328may be substantially vertical (for example, substantially perpendicular to the surface332), substantially horizontal (for example, substantially parallel to the surface332), or may comprise any other combination of horizontal and vertical sections. While a land-based system300is illustrated inFIG. 3, electronic initiator sleeves incorporating teachings of the present disclosure may be satisfactorily used with drilling equipment located on offshore platforms, drill ships, semi-submersibles, and drilling barges (not expressly shown). One or more casing strings310may extend into the wellbore328from a wellhead312.

Well system300depicted inFIG. 3is generally known as a closed wellbore in which one or more casing strings310are inserted in vertical section304, bend308, and horizontal section306and cemented in place with a cement sheath330surrounding casing strings310. As used herein, the term “closed wellbore” refers to a wellbore comprising a substantially unperforated or unbroken cement sheath in which there is no substantial fluid flowing from the wellbore into to the subterranean formation. In some embodiments, the wellbore328may be partially completed (for example, partially cased or cemented) and partially uncompleted (for example, uncased and/or uncemented). In other embodiments, the wellbore328may be open if casing strings310do not extend through bend308and/or horizontal section306of the wellbore328.

The embodiment inFIG. 3includes a top production packer314disposed in the vertical section304of the wellbore that seals against an innermost surface of the casing string310. A tubular string316extends from wellhead312along the wellbore. Tubular string316may be a casing string, a liner, a work string, a coiled tubing string, or other tubular string as will be appreciated by one of skill in the art with the benefit of this disclosure. Tubing string316may also be used to inject fluids into the formation326via the wellbore. Tubular string316may include multiple sections that are coupled or joined together by any suitable mechanism to allow tubular string316to extend to a desired or predetermined depth in the wellbore.

Electronic initiator sleeve100may be configured for incorporation into tubular string316or another suitable tubular string. Although only one electronic initiator sleeve is depicted inFIG. 3, multiple electronic initiator sleeves may be utilized in a single wellbore. In such embodiment, housing102may comprise a suitable connection (e.g., an internal or external threaded surfaces) to allow for its incorporation into tubular string316. Other suitable connections will be known to those of skill in the art with the benefit of this disclosure. As shown inFIG. 3, in certain embodiments, electronic initiator sleeve100may be positioned on or about tubular string316at a location farthest from wellhead312. In other words, electronic initiator sleeve100may be the first or initial tool on tubular string316.

In certain embodiments, electronic initiator sleeve100may be incorporated into a plug and perforation system. In other embodiments, electronic initiator sleeve100may be incorporated into a multi-stage fracturing system. In these embodiments, various other downhole tools may be disposed along tubular string316as would be appreciated by one of skill in the art with the benefit of this disclosure. Such downhole tools include, but are not limited to, barriers318A-E and sleeves320A-E. Barriers318A-E engage the inner surface of horizontal section306, dividing the horizontal section306into a series of production zones320A-F. In some embodiments, suitable barriers318A-E include, but are not limited to packers (e.g., compression set packers, swellable packers, inflatable packers), cement, any other downhole tools, equipment, or devices for isolating zones, or any combination thereof.

The operation of electronic initiator sleeve100will now be described. In certain embodiments, electronic initiator sleeve100may be disposed within a closed wellbore penetrating at least a portion of subterranean formation326, as illustrated inFIG. 3. In certain embodiments, it may be desirable to test the integrity of casing string310in the closed wellbore328prior to establishing fluid communication between the closed wellbore328and subterranean formation326. In such embodiments, the pressure inside the closed wellbore328may be increased for a period of time. One of skill in the art with the benefit of this disclosure will recognize the appropriate pressures and time periods at which to test the integrity of casing string310.

In certain embodiments, one or more wellbore conditions as described above may be adjusted following the casing integrity test to generate one or more signals. Various types of equipment may be located at well surface332, well site302, or within the wellbore328and used to generate a predetermined signal, for example, a wireless signal. Such equipment includes, but is not limited to, a rotary table, completion, drilling, or production fluid pumps, tools or devices that can provide pressure and/or bleed off pressure, any tools or devices capable of generating an acoustic signal, fluid tanks and other completion, drilling, or production equipment. For example, well system300may include a well flow control324. Well flow control324may include, without limitation, valves, sensors, instrumentation, tubing, connections, chokes, bypasses, any other suitable components to control fluid flow into and out of the wellbore328, or any combination thereof. In operation, well flow control324controls the flow rate of one or more fluids. In one or more embodiments, an operator or well flow control324or both may regulate the pressure in the wellbore328by adjusting the flow rate of a fluid into the wellbore328. Similarly, an operator or controller or both may adjust other wellbore conditions using various types of equipment located at the well surface332, well site302, or within the wellbore328to generate the predetermined signal as would be appreciated by one of skill in the art.

As described above, actuator108may be actuated in response to the predetermined signal to transition sleeve106from a closed position to an open position. In such embodiments, a route of fluid communication from the closed wellbore328to subterranean formation326may be established through port104of electronic initiator sleeve100. For example, this route of fluid communication may be an initial route of fluid communication. In certain embodiments, the route of fluid communication may break the cement sheath330to establish fluid flow between the wellbore328and subterranean formation326. In certain embodiments, this may be the first or initial route of fluid communication established between the closed wellbore328to the subterranean formation326thereby opening the closed wellbore328. In certain embodiments, a dissolvable plug may be exposed when sleeve106transitions from a closed position to an open position. In such embodiments, the dissolvable plug may be located in port104of electronic initiator sleeve100. In such embodiments, the fluid in the wellbore328may at least partially dissolve the dissolvable plug before the route of fluid communication is established between the closed wellbore328and subterranean formation326. Once the cement sheath330is broken and/or an initial route of fluid communication is established between the closed wellbore328and subterranean formation326, further wellbore operations (e.g., plug and perforation operations or ball drop operations) may commence.

During one or more wellbore operations, each of the sleeves320A-E depicted inFIG. 3may generally operable between an open position and a closed position such that in the open position, the sleeves320A-E allow communication of fluid between the tubular string316and the production zones322A-E. In one or more embodiments, the sleeves320A-E may be operable to control fluid in one or more configurations. For example, the sleeves320A-E may operate in an intermediate configuration, such as partially open, which may cause fluid flow to be restricted, a partially closed configuration, which may cause fluid flow to be less restricted than when partially open, an open configuration which does not restrict fluid flow or which minimally restricts fluid flow, a closed configuration which restricts all fluid flow or substantially all fluid flow, or any position in between.

During production, fluid communication is generally from subterranean formation326, through the sleeves320A-E and electronic initiator sleeve100(for example, in an open configuration) and into tubular string316. Communication of fluid may also be from tubular string316, through the sleeves320A-E and electronic initiator sleeve100, and into the formation326, as is the case during hydraulic fracturing. Hydraulic fracturing is a method of stimulating production of a well and generally involves pumping specialized fracturing fluids down the well and into the formation. As fluid pressure is increased, the fracturing fluid creates cracks and fractures in the formation and causes them to propagate through the formation. As a result, the fracturing creates additional communication paths between the wellbore328and the subterranean formation326. Communication of fluid may also arise from other stimulation techniques, such as acid stimulation, water injection, and carbon dioxide (CO2) injection.

Although well system300depicted inFIG. 3comprises sleeves320A-E and barriers318A-E, it may comprise any number of additional downhole tools, including, but not limited to screens, flow control devices, slotted tubing, additional packers, additional sleeves, valves, flapper valves, baffles, sensors, and actuators. The number and types of downhole tools may depend on the type of wellbore, the operations being performed in the wellbore, and anticipated wellbore conditions. For example, in certain embodiments, downhole tools may include a screen to filter sediment from fluids flowing into the wellbore. In addition, although well system300depicted inFIG. 3depicts fracturing tools, the methods and systems of the present disclosure may be used with any downhole tool or downhole operation.

An embodiment of the present disclosure is a method including: disposing an electronic initiator sleeve within a closed wellbore penetrating at least a portion of a subterranean formation, wherein the electronic initiator sleeve comprises: a housing having at least one port, a sleeve in a closed position, an actuator, and at least one sensor; increasing fluid pressure within the closed wellbore for a period of time, wherein the sleeve remains in the closed position during the period of time; detecting a signal with the at least one sensor; and actuating the actuator in response to the signal to transition the sleeve from the closed position to an open position.

Another embodiment of the present disclosure is an electronic initiator sleeve comprising: a housing comprising one or more ports; at least one sensor coupled to the housing; a sleeve disposed within the housing that is configured to transition from a closed position to an open position exposing the one or more ports; an actuator disposed within the housing, wherein the actuator actuates in response to detection of a signal by the at least one sensor and to maintain the sleeve in the closed position until actuated; and a shear pin that maintains the sleeve in the closed position until sheared.

Another embodiment of the present disclosure is a system comprising: a wellbore having a wellhead; a tubular string disposed within the wellbore and depending from the wellhead; an electronic initiator sleeve incorporated into the tubular string in a position farthest from the wellhead, wherein the electronic initiator sleeve comprises: a housing comprising one or more ports; at least one sensor coupled to the housing; an actuator disposed within the housing that actuates in response to detection of a signal by the at least one sensor; and a sleeve disposed within the housing that is configured to transition from a closed position to an open position upon actuation of the actuator.