Patent Publication Number: US-10316619-B2

Title: Systems and methods for stage cementing

Description:
TECHNICAL FIELD 
     The present disclosure relates to apparatus, systems, and methods for stage cementing and, more particularly, stage cementing of a casing string in a wellbore. 
     BACKGROUND 
     Stage-cementing tools, or differential valve (DV) tools, are used to cement casing sections behind the same casing string, or to cement a critical long section in multiple stages. Stage cementing may reduce mud contamination and lessens the possibility of high filtrate loss or formation breakdown caused by high hydrostatic pressures, which is often a cause for lost circulation. In a multi-stage cementing process, a first (or bottom) cement stage is pumped through a cementing tool to the end of the casing and up an annulus to a calculated-fill volume (e.g., height). Then, a shutoff or bypass plug can be dropped or pumped in the casing to seal the first stage. Next, a free-fall or pump-down plug may be used to hydraulically set and open the stage tool (e.g., lower most in the case multiple stage tools are used), allowing the second (or top) cement stage to be displaced above the stage tool (e.g., lower most in the case multiple stage tools are used). A closing plug is then pumped down to close the stage tool (e.g., lower most in the case multiple stage tools are used) to keep cement from U-tubing above and back through the tool. In the event an additional (upper) stage tool is used, the above process repeats itself with the exception that only a free fall plug is used to hydraulically set and open the stage tool, allowing for the third cement stage to be displaced above the upper stage tool. Often, stage cementing tools do not open or close properly when using pumped or dropped plugs. Further, there may be leakages of cement around the plugs and through the stage tools. 
     SUMMARY 
     In an example implementation, a stage cementing tool includes a top sub-assembly configured to couple to a portion of a casing string; a bottom sub-assembly configured to couple to another portion of the casing string; a housing that connects the top and bottom sub-assembly and includes a bore therethrough from the top sub-assembly to the bottom sub-assembly, the housing including a plurality of ports radially arranged in the housing, each port including a fluid path between an interior radial surface of the housing and an outer radial surface of the housing; at least one sleeve that rides on a portion of the housing; and a controller mounted in the housing and configured to control the sleeve to adjust, based on receipt of a command to the controller from the terranean surface, between a first position such that the sleeve mandrel decouples fluid communication from the bore to an exterior of the housing through the fluid paths and a second position such that the sleeve mandrel fluidly couples the bore with the exterior of the housing through the fluid paths. 
     An aspect combinable with the example implementation further includes a hydraulic power unit communicably coupled to the controller and configured to adjust the sleeve between the first and second positions. 
     In another aspect combinable with any of the previous aspects, the at least one sleeve includes a plurality of sleeves, each sleeve associated with one of the plurality of ports. 
     In another aspect combinable with any of the previous aspects the hydraulic power unit includes a plurality of hydraulic fluid cavities, each cavity aligned with one of the plurality of ports and at least partially filled with a hydraulic fluid; and at least one pump fluidly coupled to the hydraulic fluid cavities to circulate the hydraulic fluid in each hydraulic fluid cavity against a respective sleeve. 
     In another aspect combinable with any of the previous aspects, the controller is communicably coupled to the pump and operable to activate the pump to circulate the hydraulic fluid into a plurality of slots and against the plurality of sleeves to move the sleeves on the housing within respective slots to align a bore of each sleeve with the port in the second position. 
     Another aspect combinable with any of the previous aspects further includes a plurality of biasing members. 
     In another aspect combinable with any of the previous aspects, each biasing member is mounted in the housing adjacent a respective sleeve. 
     In another aspect combinable with any of the previous aspects, the controller is communicably coupled to the pump and operable to deactivate the pump to allow the hydraulic fluid to flow into the hydraulic fluid cavities, and each biasing member is configured to urge the respective sleeve on the housing to misalign the bore of each sleeve with the port in the first position. 
     Another aspect combinable with any of the previous aspects further includes a plurality of valves. 
     In another aspect combinable with any of the previous aspects, each valve is fluidly coupled between a respective hydraulic fluid cavity and a respective slot. 
     Another aspect combinable with any of the previous aspects further includes at least one pressure sensor mounted in the housing to detect a fluid pressure of the hydraulic fluid, the at least one pressure sensor communicably coupled to the controller. 
     In another aspect combinable with any of the previous aspects, the controller includes a wireless transceiver configured to communicate with a stage cementing control system at the terranean surface. 
     In another example implementation, a method for cementing a casing in a wellbore includes receiving, at a stage cementing tool coupled within a casing string in a wellbore, a wireless command from a stage cementing control system at a terranean surface; based on the wireless command, operating a hydraulic power unit mounted in a housing of the stage cementing tool to pressurize a hydraulic fluid stored in a hydraulic fluid cavity of the housing; urging, with the pressurized hydraulic fluid, at least one sleeve positioned to ride on a portion of the housing from a first position to a second position; based on urging of the at least one sleeve from the first position to the second position, fluidly coupling a bore of the housing defined by an inner radial surface of the housing to an annulus of the wellbore adjacent an outer radial surface of the housing; and circulating a flow of cement from the bore, through at least one port defined in the housing between the inner and outer radial surfaces, and to the annulus. 
     Another aspect combinable with any of the previous aspects further includes receiving, at the stage cementing tool, another wireless command from the stage cementing control system at the terranean surface; based on the other wireless command, operating the hydraulic power unit to depressurize the hydraulic fluid; urging, with a biasing member mounted in the housing, the at least one sleeve from the second position to the first position; based on urging of the at least one sleeve from the second position to the first position, fluidly decoupling the bore of the housing with the annulus; and stopping the flow of cement, with the sleeve, through the port defined in the housing between the inner and outer radial surfaces. 
     In another aspect combinable with any of the previous aspects, the at least one sleeve includes a plurality of sleeves, each sleeve associated with one of a plurality of ports. 
     Another aspect combinable with any of the previous aspects further includes operating the hydraulic power unit to pressurize the hydraulic fluid stored in a plurality of hydraulic fluid cavities of the housing; urging, with the pressurized hydraulic fluid in each hydraulic fluid cavity, a respective sleeve of the plurality of sleeves from the first position to the second position; and based on urging each of the sleeves from the first position to the second position, fluidly coupling the bore of the housing to the annulus of the wellbore adjacent the outer radial surface of the housing through a respective port of a plurality of ports in the housing 
     In another aspect combinable with any of the previous aspects, operating the hydraulic power unit to pressurize the hydraulic fluid stored in the plurality of hydraulic fluid cavities of the housing includes operating at least one pump to pressurize the hydraulic fluid in the plurality of hydraulic fluid cavities; and circulating the pressurized hydraulic fluid into a plurality of slots and against the plurality of sleeves to move the sleeves on the housing within respective slots to align a bore of each sleeve with the port to adjust the sleeves to the second position. 
     In another aspect combinable with any of the previous aspects, operating the hydraulic power unit to depressurize the hydraulic fluid includes deactivating at least one pump in fluid communication with the hydraulic fluid cavity; an allowing the pressurized hydraulic fluid to flow back into the hydraulic fluid cavity. 
     Another aspect combinable with any of the previous aspects further includes wirelessly transmitting, from the stage cementing tool to the stage cementing control system, data associated with operation of the stage cementing tool to the stage cementing control system. 
     In another aspect combinable with any of the previous aspects, the data includes at least one of a power status of the stage cementing tool, a sensed pressure of the hydraulic fluid, or an electronic status of the stage cementing tool. 
     Another aspect combinable with any of the previous aspects further includes supplying power to at least one of a controller or the power unit of the stage cementing tool with a battery mounted in the housing. 
     In another aspect combinable with any of the previous aspects, the stage cementing tool includes a first stage cementing tool. 
     In another aspect combinable with any of the previous aspects further includes, subsequent to stopping the flow of cement with the sleeve through the port defined in the housing between the inner and outer radial surfaces, receiving, at a second stage cementing tool coupled within the casing string in the wellbore, another wireless command from the stage cementing control system at the terranean surface; based on the other wireless command, operating a hydraulic power unit mounted in a housing of the second stage cementing tool to pressurize a hydraulic fluid stored in a hydraulic fluid cavity of the housing; urging, with the pressurized hydraulic fluid, at least one sleeve positioned to ride on a portion of the housing from a first position to a second position; based on urging of the at least one sleeve from the first position to the second position, fluidly coupling a bore of the housing defined by an inner radial surface of the housing to the annulus of the wellbore adjacent an outer radial surface of the housing; and circulating another flow of cement from the bore, through at least one port defined in the housing between the inner and outer radial surfaces, and to the annulus. 
     In another example implementation, a stage cementing system includes a stage cementing control system positioned on a terranean surface and configured for wireless communication; and a first stage cementing tool configured to couple within a production casing string in a wellbore. The first stage cementing tool includes a housing that includes a bore therethrough; a plurality of ports radially about the housing, each port including a flow path between the bore and an outer radial surface of the housing; a plurality of sleeve mandrels, each sleeve mandrel positioned to ride the housing to orthogonally intersect a respective port of the plurality of ports; and a controller mounted in the housing and configured for wireless communication with the stage cementing control system. The controller is configured to perform operations including: receiving a first wireless signal from the stage cementing control system; and based on the first wireless signal, operating a hydraulic power unit of the first stage cementing tool to circulate a pressurized fluid against the sleeve mandrels to urge each of the sleeve mandrels into a clearance position out of a respective port of the plurality of ports to fluidly couple the bore with an annulus of the wellbore during a first cementing operation. 
     In an aspect combinable with the example implementation, the controller is further configured to perform operations including receiving a second wireless signal from the cementing control system; and based on the second wireless signal, operating the hydraulic power unit to depressurize the pressurized fluid against the sleeve mandrels. 
     In another aspect combinable with any of the previous aspects, the stage cementing tool further includes a plurality of springs, each spring positioned to urge a respective sleeve mandrel in a direction opposite a flow of the pressurized fluid to fluidly decouple the bore with the annulus of the wellbore during the first cementing operation. 
     Another aspect combinable with any of the previous aspects further includes a second stage cementing tool configured to couple within the production casing string in the wellbore. 
     In another aspect combinable with any of the previous aspects, the second stage cementing tool includes a housing that includes a bore therethrough; a plurality of ports radially about the housing, each port including a flow path between the bore and an outer radial surface of the housing; a plurality of sleeve mandrels, each sleeve mandrel positioned to ride the housing to orthogonally intersect a respective port of the plurality of ports; and a controller mounted in the housing and configured for wireless communication with the stage cementing control system. The controller of the second stage cementing tool is configured to perform operations including: receiving a third wireless signal from the stage cementing control system; and based on the third wireless signal, operating a hydraulic power unit of the second stage cementing tool to circulate a pressurized fluid against the sleeve mandrels to urge each of the sleeve mandrels into a clearance position out of a respective port of the plurality of ports to fluidly couple the bore with the annulus of the wellbore during a second cementing operation. 
     Implementations according to the present disclosure may include one or more of the following features. For example, a stage cementing tool according to the present disclosure may be wirelessly operated (e.g., by Wi-Fi transmission or electromagnetics) while positioned on a production casing in a wellbore. As another example, a stage cementing tool according to the present disclosure may be activated (e.g., opened) and deactivated (e.g., closed) multiple times within a cementing operation. A stage cementing tool according to the present disclosure may also provide real-time diagnostic information (e.g., about a state of the tool, about a state of a cementing operation) to a control system for the cementing operation. As another example, a stage cementing tool according to the present disclosure may operate to circulate cement to an annulus between a casing and a wellbore without opening or closing plugs or making clean-out runs. As yet another example, a stage cementing tool according to the present disclosure may be part of a system which includes multiple, independently operable stage cementing tools positioned in a casing string. Further, a stage cementing tool according to the present disclosure may eliminate or help eliminate costs and mechanical failures associated with plug operated tools that often result in additional trips, time delays and potential remedial cementing operations. 
     The details of one or more implementations of the subject matter described in this disclosure are set forth in the accompanying drawings and the description below. Other features, aspects, and advantages of the subject matter will become apparent from the description, the drawings, and the claims. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
         FIG. 1  is a schematic illustration of an example implementation of a stage cementing system according to the present disclosure. 
         FIG. 2A  is a schematic illustration of an example implementation of a stage cementing tool for a stage cementing system according to the present disclosure. 
         FIG. 2B  is a schematic cross-sectional view of the example implementation of the stage cementing tool in a closed position according to the present disclosure. 
         FIG. 2C  is a schematic cross-sectional view of the example implementation of the stage cementing tool in an open position according to the present disclosure. 
         FIG. 3  is a flowchart that illustrates an example stage cementing method according to the present disclosure. 
     
    
    
     DETAILED DESCRIPTION 
     The present disclosure describes a stage cementing tool and system for a cementing process to set a casing into a wellbore. In some aspects, the stage cementing tool may be wirelessly activated by a surface control system to open one or more ports in the tool to fluidly connect the casing with an annulus of the wellbore. Cement may be circulated through the one or more ports and into the annulus to set the casing in the wellbore. In some aspects, there may be multiple stage cementing tools coupled within the casing string. Each stage cementing tool may be serially activated (e.g., one or more times) to open, allowing cement, or other fluids, to flow into the annulus, as well as serially deactivated (e.g., one or more times) to close. 
       FIG. 1  is a schematic illustration of an example implementation of a stage cementing system  100 . As shown in  FIG. 1 , a wellbore  104  is formed from a terranean surface  102  to one or more subterranean zones  106 . Although shown as a wellbore  104  that extends from land, the wellbore  104  may be formed under a body of water rather than the terranean surface  102 . For instance, in some embodiments, the terranean surface  102  may be an ocean, gulf, sea, or any other body of water under which hydrocarbon-bearing, or water-bearing, formations may be found. In short, reference to the terranean surface  102  includes both land and water surfaces and contemplates forming and/or developing one or more wellbores  104  from either or both locations. 
     Generally, the wellbore  104  may be formed by any appropriate assembly or drilling rig used to form wellbores or boreholes in the Earth. A drilling assembly may use traditional techniques to form such wellbores or may use nontraditional or novel techniques. In some embodiments, a drilling assembly may use rotary drilling equipment to form such wellbores. Although shown as a substantially vertical wellbore (e.g., accounting for drilling imperfections), the wellbore  104 , in alternative aspects, may be directional, horizontal, curved, multi-lateral, or other form other than merely vertical. 
     Once the wellbore  104  is formed (or in some cases during portions of forming the wellbore  104 ), one or more tubular casings may be installed in the wellbore  104 . As illustrated, the wellbore  104  includes a conductor casing  108 , which extends from the terranean surface  102  shortly into the Earth. A portion of the wellbore portion  104  enclosed by the conductor casing  108  may be a large diameter borehole. 
     Downhole of the conductor casing  108  may be the surface casing  110 . The surface casing  110  may enclose a slightly smaller borehole and protect the wellbore  104  from intrusion of, for example, freshwater aquifers located near the terranean surface  102 . Downhole of the surface casing  110  (or, in some aspects, an additional intermediate casing), is a production casing  111 , that is formed of production casing joints  112  (or casing joints  112 ). Generally, each casing joint  112  is a tubular that may be coupled (e.g., threadingly) to another casing joint  112 , or as shown in  FIG. 1 , a stage cementing tool  116  according to the present disclosure. The production casing  111 , generally, may be installed adjacent or across a hydrocarbon bearing reservoir, e.g., subterranean zone  106 . Completion components, such as perforating, hydraulic fracturing, acidizing, artificial lift components, are subsequently installed within the production casing  111  to produce hydrocarbons from the subterranean zone  106  to the terranean surface  102 . 
     In the illustrated implementation, the production casing  111  (and other casings shown herein) may be installed, or set, in the wellbore  104  with cement (or other hardenable substance capable of setting the casing  111  in the wellbore  104 . For example, cement  120  may be circulated from surface cementing equipment  118  into the production casing  111  from the terranean surface, through one or more of the stage cementing tools  116  installed in the production casing  111  (or other casings, such as an intermediate casing), and into an annulus  114  between the casing  111  and the wellbore  104 . Once the cement  120  fills the annulus  114  and hardens, the production casing  111  (and other casings) may be set into the wellbore  104 , thereby allowing completion operations to commence. 
     The schematic representation of the surface cementing equipment  118  includes, for example, one or more pumps, valves, and conduits that are fluidly coupled to a source of cement, such as cement mixed and/or stored in one or more tanks of the system  118 . The surface cementing equipment  118  also includes or is communicably coupled to a stage cementing control system  122  (e.g., which is communicably coupled to control the one or more pumps and one or more valves of the system  118 ). Generally, the stage cementing control system  122  may include a processor or micro-processor, hydraulic, pneumatic, mechanical, electro-mechanical, or electric (or combination thereof) control system operable to communicate with the stage cementing tools  116  (e.g., wirelessly) to send commands to and receive data from the stage cementing tools  116  to initiate, execute, and complete a stage cementing operation to set the production casing  111  into the wellbore  104  with the cement  120 . 
     In this example implementation, each of the stage cementing tools  116  (as described in more detail with reference to  FIGS. 2A-2C ) may wirelessly communicate with the stage cementing control system  122  to receive commands from, and send feedback data to, the control system  122 . For example, in some aspects, the tools  116  may wirelessly (e.g., through Wi-Fi, electromagnetics, or other wireless communication) communicate with the stage cementing control system  122  to receive commands to open (e.g., to allow the cement  120  to flow from the production casing  111  into the annulus  114 ) or to close (e.g., to stop the cement  120  from flowing from the production casing  111  into the annulus  114 ). In some aspects, each of the stage cementing tools  116  may send (e.g., wirelessly) data associated with, for example, the operation or state (e.g., open or closed) of the tool  116  to the stage cementing control system  122 . 
     The example system  100  may perform a cementing operation to set the production casing  111  (and/or other casings) into the wellbore  104  in two or more stages. For example, each “stage” may include flowing the cement  120  into the casing  111 , through at least one of the stage cementing tools  116 , and into the annulus  114  to fill a portion of the annulus  114  (less than the full annulus  114 ) with cement  120 . For example, a first stage of the cementing operation may include circulating a portion of cement  120  through a downhole-most stage cementing tool  116  (e.g., the tool  116  closest downhole to the true vertical depth of the wellbore  104 ) and filling the annulus  114  between the downhole-most stage cementing tool  116  and the next most-downhole stage cementing tool  116 . A second stage of the cementing operation may include circulating another portion of cement  120  through the next most-downhole cementing tool  116  and filling the annulus  114  between the next-most downhole stage cementing tool  116  and the stage cementing tool  116  that is uphole of the next-most downhole stage cementing tool  116 . Additional stages can be completed to fill (e.g., all or substantially) the annulus  114  with cement  120 . 
     In some aspects, each stage cementing tool  116  may be a stand-alone (e.g., not physically coupled or attached to the stage cementing control system  122 ) downhole tool operable to open, or close, one or more ports of the tool to circulate a flow, or stop a flow, of the cement  120  from the production casing  111  into the annulus  114 . For example, each stage cementing tool  116  may be individually and independently activated (e.g., by the stage cementing control system  122 ) multiple times during a cementing operation without mechanical intervention, hydraulic intervention, or both (e.g., in order to activate). For instance, each stage cementing tool  116  may be activated and deactivated by wireless signals rather than, e.g., differential pressure, a setting tool, a plug, a pumped-in or dropped dart, or other mechanical or hydraulic tool. In addition, each stage cementing tool  116  may wirelessly communicate data (e.g., state of the tool, state of the cementing operation, diagnostic information of the tool, and otherwise) to the stage cementing control system  122 . As such, the stage cementing tool  116  may monitor the integrity of the entire stage cementing system in real-time (e.g., during execution of the stage cementing operation) and eliminate the use of plug activation, which can become damaged get stuck inside the casing string prior to it arriving at a proper landing spot. 
       FIGS. 2A-2C  are schematic illustrations of an example implementation of a stage cementing tool  200  for a stage cementing system. For example, in some aspects, the stage cementing tool  200  may be used in the stage cementing system  100  as stage cementing tool  116 .  FIG. 2A  is a schematic illustration of the stage cementing tool  200  positioned in the wellbore  104  and coupled between casing joints  112 .  FIG. 2B  is a schematic cross-sectional view of the stage cementing tool  200  positioned in the wellbore  104  and in a closed position.  FIG. 2C  is a schematic cross-sectional view of the stage cementing tool  200  positioned in the wellbore  104  and in an open position. 
     The illustrated implementation of the stage cementing tool  200  includes a housing  202  that couples to the casing joints  112  (at a top, or uphole, end of the tool  200  and a bottom, or downhole, end of the tool  200 ). As shown in  FIGS. 2B-2C , a top sub-assembly  206  of the housing  202  couples (e.g., threadingly) to a casing joint  112 , and a bottom sub-assembly  208  couples (e.g., threadingly) to another casing joint  112 . An inner radial surface  203  of the housing  202  defines a bore  201  that extends through the stage cementing tool  200 , which is aligned with bores of the casing joints  112  as illustrated. An outer radial surface  204  of the stage cementing tool  200  is positioned, when the stage cementing tool  200  is coupled to the casing joints  112 , in the annulus  114 . 
     As illustrated, multiple ports  204  extend through the housing  202  between the inner radial surface  203  and the outer radial surface  204 . In this example implementation, there are four ports  204  that are radially arranged at 90° intervals around the housing  202 . Each port  204  may provide a fluid pathway (closeable) between the bore  201  and annulus  114 , e.g., to facilitate a flow of the cement  120  from the bore  201  to the annulus  114 . In alternative implementations, there may be more or fewer ports  204 , and each port  204  may have a circular or non-circular cross section. 
     As shown in  FIGS. 2B-2C , the housing  202  of the stage cementing tool  200  encloses actuation components that facilitate activation of the stage cementing tool  200  (e.g., from a closed position to an open position). For example, a controller  212  that includes one or more processors  215  and at least one wireless transceiver  213  is enclosed within the housing  202 . The controller  212 , for example, comprises an interface between the stage cementing tool  200  and the stage cementing control system  122 , or other control system for the cementing operation located at the terranean surface  102 . The controller  212 , utilizing the one or more processors  215 , the wireless transceiver  213 , and memory (e.g., as part of the stage cementing control system  122 ), may also manage communications between the stage cementing tool  200  and the stage cementing control system  122 . The processor(s)  215 , for instance, may process information from the tool  200  and the terranean surface  102 , deliver diagnostic data of the stage cementing tool  200  (and functionality) in real time, identifying if any failure has occurred with the stage cementing tool  200  during a cementing operation or otherwise. The communication between the processor(s)  215  and the terranean surface  102  is facilitated through and with the transceiver  213  with wireless communication. 
     Electrical power is provided to the controller  212  by a power source  210  (e.g., battery). In some aspects, the power source  210  is a lithium battery that is electrically coupled to the controller  212 , as well as a hydraulic power unit  216 . The controller  212  may also be communicably coupled to the power source  210 , e.g., to determine or receive a level or life of the power source  210 . 
     As shown in  FIGS. 2B-2C , each port  204  is associated with a respective power unit  216  that operates, for instance, to block or unblock the port  204  to fluidly couple or fluidly decouple the bore  201  from the annulus  114  through the respective port  204 . In this example implementation, the hydraulic power unit  216  includes, for each respective port  204 , a hydraulic fluid reservoir  214  that encloses a fluid, a valve  218  fluidly coupled to the reservoir  214 , and a sleeve mandrel  220  that is positioned to move within a fluid cavity  234  to block (or unblock) the port  204 . As shown, the sleeve mandrel  220  includes a bore  224  therethrough, as well as a block  222  (e.g., a solid portion) that is downhole of the bore  220 . 
     As illustrated in this example, a biasing member  226  (e.g., spring, Bellville washers) is positioned in the fluid cavity  234  at a bottom end of the cavity  234 . The biasing member  226 , in some aspects, may be a compression spring that exerts a particular spring force sufficient to urge the sleeve mandrel  220  in an uphole direction (e.g., toward the valve  218 ) based on a pressure balance between the fluid  219  circulated into the fluid cavity  234  and the spring force. 
     In an example operation to activate the stage cementing tool  200  into an open position, as shown in  FIG. 2B , first, the controller  212  may obtain or receive a command, through the transceiver  213 , from the stage cementing control system  122  at the terranean surface  102  to activate. Next, the one or more processors  215  analyze the command and, determining that the command is to activate the stage cementing tool  200 , the processor(s)  215  send a command to the power unit  216  (e.g., via a wired control  228 ). For example, the processor(s)  215  may send a signal to a pump  217  in the hydraulic power unit  216  to pressurize the fluid  219  in the reservoir  214 . In some aspects, the processor(s)  215  may also command an actuator  230  of the valve  218  to open upon activation of the pump  217 , thereby allowing the pump  217  to transfer the fluid  219  from the reservoir  214  into the fluid cavity  234 . As the fluid  219  flows into the fluid cavity  234 , the pressurized fluid is at or increases to a pressure on the sleeve mandrel  220  that is greater than the spring force of the biasing member  226 , and the sleeve mandrel  220  is urged in a downhole direction. As the bore  224  of the sleeve mandrel  220  aligns with the port  204  (and the block  222  is moved downhole of the port  204  and misaligned with the port  204 ), fluid (e.g., cement) communication is established between the bore  201  and the annulus  114 . In some aspects, the processor(s)  215  may close the valve  218  (e.g., through the actuator  230 ), to hold the fluid  219  in the fluid cavity  234  at a pressure above the spring force of the biasing member  226 . 
     Upon opening of the ports  204 , the power unit  216  may provide a status (e.g., “open”) to the processor(s)  215 . In some aspects, a pressure sensor  236  positioned to measure a pressure of the fluid  219  may send the measured pressure to the processor(s)  215 . The processor(s)  215  may then send the status data, pressure data, and other data (e.g., battery life) to the stage cementing control system  122  through the transceiver  113 . Thus, the stage cementing control system  122  may receive confirmation that the stage cementing tool  200  is open and able to facilitate a flow of the cement  120  to the annulus  114 . 
     In an example operation to deactivate the stage cementing tool  200  to a closed position, as shown in  FIG. 2C , first, the controller  212  may obtain or receive a command, through the transceiver  213 , from the stage cementing control system  122  at the terranean surface  102  to deactivate. Next, the one or more processors  215  analyze the command and, determining that the command is to deactivate the stage cementing tool  200 , the processor(s)  215  send a command to the power unit  216  (e.g., via a wired control  228 ). For example, the processor(s)  215  may send a signal to the pump  217  in the hydraulic power unit  216  to depressurize the fluid  219  (e.g., stop pumping), thereby allowing the fluid  219  to flow from the fluid cavity  234  back into the reservoir  214 . In some aspects, the processor(s)  215  may also command the actuator  230  of the valve  218  to open upon or prior to deactivation of the pump  217 , thereby allowing the fluid  219  to flow back into the reservoir  214  from the fluid cavity  234 . As the fluid  219  flows from the fluid cavity  234 , the pressure exerted onto the sleeve mandrel  220  by the pressurized fluid  219  decreases, until it is less than the spring force of the biasing member  226 . The sleeve mandrel  220  is urged in an uphole direction by the biasing member  226 . As the bore  224  of the sleeve mandrel  220  misaligns with the port  204 , and the block  222  is aligned with the port  204 , fluid (e.g., cement) communication is stopped between the bore  201  and the annulus  114 . In some aspects, the block  222  of the sleeve mandrel  220 , when aligned with the port  204 , creates a fluid seal between the sleeve mandrel  220  and the port  204 . 
     Upon closing of the ports  204 , the power unit  216  may provide a status (e.g., “closed”) to the processor(s)  215 . In some aspects, the processor(s)  215  may also provide status data, pressure data, and other data (e.g., battery life) to the stage cementing control system  122  through the transceiver  113 . Thus, the stage cementing control system  122  may receive confirmation that the stage cementing tool  200  is closed. 
       FIG. 3  is a flowchart that illustrates an example stage cementing method  300 . In some aspects, the method  300  may be performed by or with the stage cementing tool  200  shown in  FIGS. 2A-2C . Alternatively, the method  300  may be performed by another stage cementing tool according to the present disclosure. In some aspects, all or part of the method  300  may be repeated for multiple stages of a cementing operation. 
     Method  300  may begin at step  302 , which includes receiving a wireless activation command from a cementing control system at a terranean surface at a stage cementing tool coupled within a casing string in a wellbore. For example, in some aspects, the cementing control system located on the terranean surface (e.g., at the wellsite) sends a wireless (e.g., Wi-Fi, electromagnetic, or otherwise) signal to one of multiple stage cementing tools that are coupled (e.g., threadingly) within a production casing in the wellbore. The stage cementing tools can be positioned at specified intervals (e.g., specified depths) in the wellbore to complete a stage cementing processing. 
     Method  300  may begin at step  304 , which includes operating a hydraulic power unit (e.g., powered by a battery in the tool) of the stage cementing tool to pressurize a hydraulic fluid based on the activation command. For example, in some aspects, a controller of the tool, which receives the activation signal, activates a pump of the hydraulic power unit to pressurize a volume of a hydraulic fluid stored in a reservoir in the tool. In some aspects, after or with activation of the pump, the controller may also open a valve that fluidly couples the reservoir with another cavity or void in a housing of the tool. 
     Method  300  may begin at step  306 , which includes urging, with the pressurized hydraulic fluid, at least one sleeve from a first position (e.g., closed) to a second position (e.g., open). For example, in some aspects, as the pressurized fluid flows into the cavity or void, which contains the sleeve, the pressurized fluid urges the sleeve in a direction through the void in the housing. In some aspects, the sleeve is moved from a position in which it blocks a flow of cement from the production casing, through the tool, and into the annulus, into a position in which the flow of cement is allowed through the tool (e.g.,  FIG. 2B ). 
     Method  300  may begin at step  308 , which includes fluidly coupling a bore of the tool defined by an inner radial surface of the housing to the annulus of the wellbore adjacent an outer radial surface of the housing. For example, in some aspects, as the sleeve moves into a position in which the flow of cement is allowed, the bore of the tool, which aligns with a bore of the production casing, is fluidly connected to the annulus. 
     Method  300  may begin at step  310 , which includes circulating a flow of cement from the bore, through at least one port defined in the housing between the inner and outer radial surfaces, and to the annulus. For example, in some aspects, the tool includes a port that is opened when the sleeve moves from a closed state, by the pressurized fluid, to an open state. The port, which extends radially through a housing of the tool, includes a fluid pathway from the bore of the tool to the annulus when the sleeve is in the open position. In some aspects, the stage cementing tool may include multiple (e.g., 2, 3, 4, 5, or more) ports, arranged radially on the housing of the tool. Thus, in some aspects, steps  306 - 310  may be performed simultaneously or substantially simultaneously for multiple ports to open the tool to allow cement to flow into the annulus. 
     Method  300  may begin at step  312 , which includes a determination of whether a wireless deactivation signal has been received at the stage cementing tool from the cementing control system. For example, in some aspects, e.g., based on a volumetric amount of cement that has been circulated to the annulus in step  310 , the cementing control system may wirelessly send a deactivation signal to the particular stage cementing tool. If the wireless deactivation signal is received by the tool, then method  300  may continue at step  314 . If not, then the method  300  may continue with step  308 . 
     Method  300  may begin at step  314 , which includes operating the hydraulic power unit to depressurize the hydraulic fluid based on the deactivation command. For example, in some aspects, based on the deactivation signal, the hydraulic power unit may signal the pump to stop pressurizing and circulating the hydraulic fluid into the cavity or void to urge the sleeve into an open position. The pressurized fluid may thus de-pressurize and at least begin to flow back into the hydraulic fluid reservoir from the cavity. The fluid pressure force on the sleeve, urging it into the open position, may therefore decrease or be removed. 
     Method  300  may begin at step  316 , which includes urging, with a biasing member mounted in the tool, the at least one sleeve from the second position to the first position. For example, in some aspects, a spring or other biasing member (e.g., Bellville washers) may be positioned at an end of the sleeve opposite the pressurized fluid. The spring has a spring force associated with it that is exerted on the sleeve. When the fluid is pressurized, e.g., by the pump, the force of the pressurized fluid may be greater than the spring force, thereby urging the sleeve (and maintaining the sleeve) into the open position. As the pressurized fluid is depressurized and the fluid force is relieved on the sleeve, the spring force may be greater than the fluid force. The spring, therefore, may urge the sleeve back into the closed position. 
     Method  300  may begin at step  318 , which includes based on urging of the at least one sleeve from the second position to the first position, fluidly decoupling the bore of the housing with the annulus. For example, in some aspects, when the sleeve is moved into the closed position (e.g.,  FIG. 2C ), the bore of the tool is fluidly decoupled from the annulus. In other words, the port or ports of the tool are closed to not allow a flow of the cement through the stage cementing tool. 
     Method  300  may begin at step  320 , which includes stopping the flow of cement, with the sleeve, through the port defined in the housing between the inner and outer radial surfaces. For example, in some aspects, once the ports are closed, the tool may be closed to any further flow of cement from the production casing to the annulus. 
     Method  300  may begin at step  322 , which includes a determination of whether there are additional stages (e.g., of the annulus) to cement in the cementing operation. For example, in some aspects, there may be several stage cementing tools coupled within a production casing. The tools may be positioned at intervals, or depths, of the casing so that cement may be circulated through each, in turn, to insert the cement in the annulus at or between particular depths of the wellbore. In some aspects, the deepest stage cementing tool in the wellbore is first activated to facilitate a flow of cement into the annulus, and then deactivated. And then a next deepest stage cementing tool is activated and so on and until the shallowest (e.g., relative to TMD of the wellbore) stage cementing tool is activated. In step  322 , if there is at least one stage cementing tool in the production casing which has not been activated, or if a previously-activated stage cementing tool needs to be re-activated, then method  300  may repeat back at step  302  and continue. If, however, no further stage cementing tools in the casing string need be activated, then method  300  may stop and the stage cementing process may be completed. 
     While this specification contains many specific implementation details, these should not be construed as limitations on the scope of any inventions or of what may be claimed, but rather as descriptions of features specific to particular implementations of particular inventions. Certain features that are described in this specification in the context of separate implementations can also be implemented in combination in a single implementation. Conversely, various features that are described in the context of a single implementation can also be implemented in multiple implementations separately or in any suitable subcombination. Moreover, although features may be described above as acting in certain combinations and even initially claimed as such, one or more features from a claimed combination can in some cases be excised from the combination, and the claimed combination may be directed to a subcombination or variation of a subcombination. 
     A number of implementations have been described. Nevertheless, it will be understood that various modifications may be made without departing from the spirit and scope of the disclosure. For example, example operations, methods, or processes described herein may include more steps or fewer steps than those described. Further, the steps in such example operations, methods, or processes may be performed in different successions than that described or illustrated in the figures. Accordingly, other implementations are within the scope of the following claims.