Patent ID: 12228012

DETAILED DESCRIPTION

In the following detailed description of embodiments of the present disclosure, numerous specific details are set forth to provide a more thorough understanding of the claimed subject matter. However, it will be apparent to one of ordinary skill in the art that the embodiments disclosed herein may be practiced without these specific details. In other instances, well-known features have not been described in detail to avoid unnecessarily complicating the description. Additionally, it will be apparent to one of ordinary skill in the art that the scale of the elements presented in the accompanying Figures may vary without departing from the scope of the present disclosure.

As used herein, the term “coupled” or “coupled to” or “connected” or “connected to” “attached” or “attached to” may indicate establishing either a direct or indirect connection, and is not limited to either unless expressly referenced as such. Wherever possible, like or identical reference numerals are used in the figures to identify common or the same elements. The figures are not necessarily to scale and certain features and certain views of the figures may be shown exaggerated in scale for purposes of clarification. In addition, any terms designating tubular (i.e., a length of pipe that provides a conduit for flow therein) should not be deemed to limit the scope of the disclosure. The embodiments are described merely as examples of useful applications, which are not limited to any specific details of the embodiments herein.

Embodiments disclosed herein relate generally to well intervention operations in oil and gas well sites. More specifically, embodiments disclosed herein relate to systems and methods for using a flapper holder tool to open a tubing-retrievable subsurface safety valve (TRSSSV) of a tubing string. In one aspect, embodiments disclosed herein pertain to when the TRSSSV fails to open or unintentionally closes, the flapper holder tool is used to open the TRSSSV to allow operations to continue, such as, running or pulling out tools safely through the failed TRSSSV.

FIG.1shows a block diagram of a well site100in accordance with one or more embodiments. The well site100includes a wellbore130in fluid communication with a hydrocarbon reservoir (“reservoir”) located in a subsurface formation (“formation”)101. The formation101may include a porous formation that resides underground, beneath the Earth's surface102. The formation101and the reservoir may include different layers of rock having varying characteristics, such as varying degrees of permeability, porosity, capillary pressure, and resistivity. In the case of the well site100being operated as a production well, the well site100may facilitate the extraction of hydrocarbons (or “production”) from the reservoir.

The wellbore130may include a bored hole that extends from the surface102into a target zone of the formation101, such as the reservoir. An upper end of the wellbore130, terminating at or near the surface102, may be referred to as the “up-hole” end of the wellbore130, and a lower end of the wellbore130, terminating in the formation, may be referred to as the “down-hole” end of the wellbore130. The wellbore130may facilitate the circulation of drilling fluids during drilling operations, the flow of production (e.g., hydrocarbons such as oil and gas) from the reservoir to the surface102during production operations, the injection of substances (e.g., water) into the formation101or the reservoir during injection operations, or the communication of monitoring devices (e.g., logging tools) into the formation101or the reservoir during monitoring operations (e.g., during in situ logging operations).

In some embodiments, the wellbore130may have a cased portion and an uncased (or “open-hole”) portion. The cased portion may include a portion of the wellbore having casing (e.g., casing pipe and casing cement) disposed therein. The uncased portion may include a portion of the wellbore not having casing disposed therein. In embodiments having a casing, the casing defines a central passage that provides a conduit for the transport of tools and substances through the wellbore130. For example, the central passage may provide a conduit for lowering logging tools into the wellbore130, a conduit for the flow of production (e.g., oil and gas) from the reservoir to the surface102, or a conduit for the flow of injection substances (e.g., water) from the surface102into the formation101.

In some embodiments, a tubular string, such as a production tubing131, may be installed in the wellbore130. The production tubing131may provide a conduit for the transport of tools and substances through the wellbore130. The production tubing131may, for example, be disposed inside casing. In such an embodiment, the production tubing131may provide a conduit for some or all of the production (e.g., oil and gas) passing through the wellbore130and the casing. Additionally, the production tubing131includes a tubing-retrievable subsurface safety valve (TRSSSV)205. The TRSSSV205makes up part of the production tubing131and is a means for safety close in the case of uncontrolled release of hydrocarbons, such as a kick. Also, the TRSSSV205may be used as a barrier when testing or is needed to perform maintenance on the wellhead130or downhole.

In some embodiments, a wellhead103may include a rigid structure installed at the “up-hole” end of the wellbore130, at or near where the wellbore130terminates at the Earth's surface102. The wellhead103may include structures (called “wellhead casing hanger” for casing and “tubing hanger” for production tubing) for supporting (or “hanging”) casing and production tubing extending into the wellbore130. Production may flow through the wellhead130, after exiting the wellbore130, including, for example, the casing and the production tubing131. Additionally, a blowout preventer (BOP)200may be coupled on top of the wellhead103. The BOP200is a valve or stacks of valves device, used to seal, control and monitor oil and gas wells to prevent blowouts, the uncontrolled release of crude oil or natural gas from the wellbore130. Further, the BOP200, or a well cap in the case where no BOP provided on the wellhead103, provides access to wellbore130for interventions with a cable such as a wireline, slickline, or coil tubing. In addition, a lubricator207may be provided on top of the BOP200to lubricate tools being sent into the wellbore130.

Still referring toFIG.1, various flow regulating devices are operable to control the flow of substances into and out of the wellbore130. For example, the wellhead103may include a crown valve201, a wing valve202, a surface safety valve203, a master valve204, and a subsurface safety valve (SSSV)104. The crown valve201is the upper most valve within the wellhead103. Typically, the crown valve201is closed until there is a need to access the wellbore130. The wing valve202is for production flow control. In the case of needing to enter the wellbore130, the wing valve202would be closed and the master valve204would be open. The surface safety valve203is typically a hydraulic failsafe close valve located at surface. The surface safety valve203may be used in the event of an issue in the wellbore/surface equipment and for testing. The master valve (204) is the main valve controlling flow from the wellbore130. Additionally, the SSSV206is another safety device located below the surface102, e.g., several hundred plus feet below the surface102. Further, a SSSV test may be conducted to confirm the SSSV206is operational. For example, the SSSV test a fitting is connected on a control line which connects to a hand pump. Next, a wellhead pressure is checked and then the wellhead pressure is bled 50%. With the wellhead pressure bleed, a user waits for 10 minutes and if there is no buildup of the pressure, then the user will operate the hand pump to pump through the control line to open the SSSV206.

Now referring toFIGS.2A and2B, a cross-section view of the TRSSSV205is illustrated. The TRSSSV205is shown in an open position inFIG.2Aand in a closed position inFIG.2B. The TRSSSV205includes a body210axially extending from a first end211to a second end212. The body210defines a bore215that provides a conduit for downhole tools and for fluids to pass through. The first end211may be a lower end which is positioned downward in the wellbore. Additionally, the first end211may include a sloped surface213to land on the ported nipple sub. The second end212may be an upper end which is positioned upward in the wellbore. Further, the second end212may be fish neck of the TRSSSV205.

In one or more embodiments, as shown inFIG.2A, the TRSSSV205includes various internal components to conduct operations. For example, a hydraulic pressure system provides power to the TRSSSV205to axially move an actuation device217to open and close a flapper218. For example, a hydraulic line216applies hydraulic pressure and moves the actuation device217, such as a piston, downward to push the flapper218into the open position, as shown inFIG.2A. Additionally, an inner diameter ID of the actuation device217may be equal to a nominal inner diameter of the TRSSSV205which limits the size of downhole tools able to pass through the TRSSSV205. With the flapper218in the open position, access to the wellbore is allowed to conduct various downhole operations such as well intervention.

As shown inFIG.2B, if the TRSSSV205fails, the actuation device217will move axially upward and allow the flapper218to move the closed position. In the closed position, the flapper218closes the bore215thereby blocking access to the wellbore. In the closed position, the TRSSSV205prevents downhole operations from being conducted which may increase NPT, damage equipment, make the work environment hazardous, or cause a total well loss. In some embodiments, if the flapper218closes during a well intervention operation, the downhole tools, such as a bottomhole assembly (BHA), cannot be pulled out-of-hole (POH) and the wireline, slickline, or coiled tubing must be cut resulting in loss of equipment (e.g., the downhole tools) downhole or having to conduct fishing operations. Alternatively, if the flapper218closes before a well intervention operation, the downhole tools, such as a bottomhole assembly (BHA), cannot be run-in-hole (RIH).

In the case that the TRSSSV205fails, to prevent the flapper218from being in the closed position blocking downhole operations, a flapper holder tool, as described below, is deployed to force open the flapper218of the TRSSSV205to allow operations to continue.

Referring toFIG.3, in one or more embodiments, a flapper holder tool300is illustrated. The flapper holder tool300includes a tubular body301formed from a body radially extending from an inner surface307to an outer surface308to define a bore306. Additionally, the tubular body301extends axially a length L from a first end302to a second end303. Further, the bore306extends the length L axially along an axis A. It is further envisioned that the bore306may have tapered diameter such that the outer surface308is a tapered outer surface and the inner surface307is tapered inner surface. For example, an inner diameter ID1at the first end302may be larger than an inner diameter ID2at the second end303such that the tubular body301progressively gets smaller from the first end302to the second end303. The inner diameter ID1may have a maximum valve equal to the inner diameter (ID) of the actuation device (217) of the TRSSSV (205) and the inner diameter ID2may have a minimum valve equal to largest outer diameter of a downhole tool that may pass through the TRSSSV (205).

At the first end302, a lip304extends radially outwardly from the tubular body301to land within the TRSSSV (205). For example, when deployed, the lip304lands atop of the TRSSSV (205). Additionally, as the lip304extends radially outward from the tubular body301, the lip304also acts as a no-go device to prevent the flapper holder tool300from failing through the TRSSSV (205). For example, the lip304sits on top of or within the TRSSSV (205). It is further envisioned that a seal305, such as an elastomer seal or O-ring, may be provided in the lip or groove304to provides a seal between the flapper holder tool300and the TRSSSV (205).

At the second end303, the tubular body301may include an engagement surface309to contact the flapper (218) of the TRSSSV (205). For example, when deployed, the engagement surface309lands on the flapper (218) and a downward force of the flapper holder tool forces the flapper (218) open. Additionally, the engagement surface309may include a rubber material or coating to prevent damage to and from the flapper (218). It is further envisioned that the tubular body301is a rigid member made of a metal, such as steel, or a resilient material (i.e., a stem or weight bar) that can provide and within stand a force to push open the flapper (218) of the TRSSSV (205).

In some embodiments, as the flapper (218) is being opened by the flapper holder tool300, the flapper (218) may scrap against the outer surface308. The outer surface308may include a coating to reduce a friction between the flapper (218) and the outer surface308. By reducing the friction, the flapper holder tool300can continue moving downward, move the flapper (218) to a fully opened position, and avoid become stuck to high up in the TRSSSV (205) from the scrapping against the outer surface308.

In one or more embodiments, the flapper holder tool300may include an internal fish neck311. For example, the internal fish neck311may be one or more grooves or notches on the inner surface307to allow a downhole tool to engage the internal fish neck311. With the downhole tool engaged to the internal fish neck311, both the downhole tool and the flapper holder tool300may be retrieved to the surface.

Still referring toFIG.3, in one or more embodiments, the tubular body301may include an opening312to receive a cable. For example, one or more ledges313may extend into the opening312to form a seat for the cable. Additionally, a plurality of set screws314may be used to close the opening312around the cable and lock the flapper holder tool300to the cable.

FIG.4is a flowchart showing a method of using the flapper holder tool300ofFIG.3at a well site (such as the well site described inFIG.1) when a cable (e.g., wireline, slickline, or coiled tubing) is deployed into the wellbore and passed the TRSSSV. One or more blocks inFIG.4may be performed by one or more components (e.g., a computing system coupled to a controller in communication with the devices at the well site100). For example, a non-transitory computer readable medium may store instructions on a memory coupled to a processor such that the instructions include functionality for deploying the flapper holder tool300. While the various blocks inFIG.4are presented and described sequentially, one of ordinary skill in the art will appreciate that some or all of the blocks may be executed in different orders, may be combined or omitted; and some or all of the blocks may be executed in parallel. Furthermore, the blocks may be performed actively or passively.

In Block400, a pressure to the TRSSSV is continuously monitored. For example, various pressure sensors positioned in the wellbore and on the surface may measure an amount of pressure being provided to the TRSSSV. The various pressure sensors transmit the measurements to a controller and/or operator to be monitored.

In Block401, the measured pressure is compared to predetermined thresholds. For example, the predetermined threshold of the pressure to the TRSSSV may be a value equal to a minimum amount of pressure (for example, a required hydraulic pressure of 4,000-10,000 psi) required to keep the TRSSSV open (i.e., the actuation device is moved to a downward position to displace the flapper to the open position). If the measured pressure has not dropped below the predetermined threshold, this indicates that the TRSSSV is maintained in the open position, thereby allowing downhole operations to be conducted as shown in Block408. However, if the measured pressure has dropped below the predetermined threshold, this indicates that the TRSSSV has failed (i.e., the actuation device has moved upward no longer engaging the flapper, and the flapper is moved to the closed position). With the TRSSSV indicated as failed, the method moves to Block402.

In addition to or as an alternative to Blocks401and402, to determine if the TRSSSV indicated has failed, a cable traveling through the TRSSSV may be pulled on to see if the cable can be moved upward or downward. If the cable can be moved upward, then the TRSSSV has not failed as the gate valve must be opened for the cable to move upward. However, if the cable cannot be moved upwards nor downwards, this indicates that the TRSSSV has failed, and the method moves to the Block402.

In Block402, with the TRSSSV indicated as failed, a valve at the wellhead or BOP is closed. If there is no BOP on top of the wellhead, the main valve of the wellhead is closed. If there is a BOP stacked on top of the wellhead, the valve of the BOP is closed. By closing the valve in the wellhead or the BOP, the wellbore is shutoff and allows surface operations to be conducted safely.

In Block403, with the valve in the wellhead or the BOP closed, the flapper holder tool is attached to a cable, such as a wireline, slickline, or coiled tubing, and run into the wellbore. For example, the flapper holder tool is placed over an end of the cable outside the wellhead or the BOP such that the cable runs through the flapper holder tool. Additionally, the cable is set within the opening of the flapper holder tool and set screws lock the cable with the flapper holder tool.

In Block404, with the flapper holder tool on the cable/wireline/tubing, the valve at the wellhead or BOP is opened to allow the flapper holder tool to travel into the wellbore. In the case of having a BOP at the well site, pressure is equalized between the BOP and lubricator before the BOP is opened

In Block405, with the valve in the wellhead or the BOP opened, the flapper holder tool is lowered into the wellbore. For example, the flapper holder tool travels along a length of the cable to reach a predetermined depth in the wellbore. The predetermined depth is a depth at which the TRSSSV is disposed within the wellbore.

In Block406, the flapper holder tool engages with the TRSSSV. For example, the lip of the flapper holder tool lands on top or within the TRSSSV. In some embodiments, the lip sits above the flapper of the TRSSSV. The lip may seal against a surface of the TRSSSV such as an upper most end of the TRSSSV.

In Block407, with the flapper holder tool landed on the TRSSSV, the flapper of the TRSSSV is opened by the flapper holder tool via the downward force from dropping the flapper holder tool. For example, an end of the tubular body of the flapper holder tool contacts the flapper and applies a downward force on the flapper to move the flapper to the open position. Additionally, as the flapper scraps against the tubular body, a coating on an outer surface of the tubular body reduces a friction between the flapper and the tubular body. Additionally, to determine if the flapper has been opened by the flapper holder tool, the cable traveling through the TRSSSV is pulled upward; and if the cable is not restricted by the flapper, the cable is able to move upward.

In Block408, with the flapper forcibly opened by the flapper holder tool, downhole operations are conducted. For example, well intervention operations such as retrieval of trapped downhole tools are conducted (i.e., rescuing downhole tools by pulling up along with the flapper holder tool). Specifically, the trapped downhole tools may be pulled upward, along the flapper holder tool, and out of the wellbore for maintenance, repair, or replacement. Additionally, a running tool may be RIH to engage the fish neck of the flapper holder tool for retrieval.

Now referringFIGS.5-9, in one or more embodiments,FIGS.5-9illustrate a system of implementing the method described in the flowchart ofFIG.4using the flapper holder tool300ofFIG.3in a well intervention operation.

InFIG.5, in one or more embodiments, a close-up view of the surface102ofFIG.1is illustrated. In a well intervention operation, a cable11is employed from a cable unit10into the wellhead103. The cable unit10may be a truck15or trailer having a drum to spool and unspool the wireline, slickline, or coiled tubing. The cable11may be inserted into the wellhead103via the lubricator207and through the BOP200rigged on top of the wellhead103. The BOP200may include a blind ram to close and seal around the cable11which allows operations to be performed under pressure, on surface equipment, when the cable11is still in the wellbore103. Then the valves of the wellhead103are opened to enable the cable11to fall or be pumped into the wellbore130under pressure.

From the wellhead103, the cable11passes through the TRSSSV205, down a tubular string, such as the production tubing131, and connects down to a bottomhole assembly (BHA)6. The BHA6may include various components such as drill bits, drill collars, mud motors, stabilizers, sensitive measurement equipment, logging while drilling (LWD) tools, measurement while drilling (MWD) tools, and various other downhole tools without departing from the scope of the present disclosure.

FIG.6illustrates a closeup cross-sectional view of the dotted box6ofFIG.5. As previously described, the TRSSSV205makes up a part of the production tubing131. In the case that the pressure system fails, the pressure within the TRSSSV205has dropped allowing the actuation device217to move axially upward and to move the flapper218out of the open position. Without the flapper218in the open position, the flapper218encounters the wire11.

Now referring toFIG.7, as the TRSSSV205has failed, the flapper holder tool300(as described inFIG.3) is deployed to move the flapper (218) back to the open position. The flapper holder tool300is attached to the cable11on the surface102. For example, the cable11is run through the second end303so that the cable11travels through the bore (306) of the tubular body301, and past the first end302to exit the flapper holder tool300. Additionally, the cable11is set on the one or more ledges (313) of the flapper holder tool300within the opening312(314) that is defined in the bore (309). Further, the plurality of set screws (314) locks the cable11to the flapper holder tool300.

With the flapper holder tool300on the cable11, pressure between the BOP200and the lubricator is equalized. After equalizing that the pressure, the BOP200is opened to allow the flapper holder tool300to be lowered in the wellbore130and land TRSSSV205. For example, the flapper holder tool300may be simply dropped down the wellbore130to generate a force downward on the TRSSSV205.

FIG.8illustrates a closeup cross-sectional view of the dotted box8ofFIG.7. As previously described, the flapper holder tool300is deployed and lowered down the production tubing131. The lip304at the first end302lands on the TRSSSV205. For example, the lip304sits on the second end212(i.e., an upper most end) of the TRSSSV205. From the first end302, the tubular body301extends downward such that the second end303forces that the flapper218to the open position. Additionally, the flapper218is contacting the outer surface308of the tubular body301. In some embodiments, a coating on the outer surface308reduces a friction between the flapper218and the tubular body301. With the flapper218back in the open position, well intervention operations may continue.

Now referring toFIG.9, with the flapper holder tool300landed on the TRSSSV205and moving the flapper218to the open position, a running/pulling tool220may be sent into the wellbore130to retrieve the flapper holder tool300and/or the BHA6. The running/pulling tool220may be lowered into the first end302to engage the internal fish neck311. Once engaged with the internal fish neck311, the running/pulling tool220may be move upward (see block Arrow U) via the cable11to retrieve the flapper holder tool300and/or the BHA6. As the BHA6travels upward, the BHA6will engage the flapper holder tool300. The BHA6and the flapper holder tool300may be raised together to the surface (108) for maintenance, repairs, or replacement.

FIG.10is a flowchart showing another method of using the flapper holder tool300ofFIG.3at a well site (such as the well site described inFIG.1) when the cable (e.g., wireline, slickline, or coiled tubing) has not yet passed through the TRSSSV. One or more blocks inFIG.10may be performed by one or more components (e.g., a computing system coupled to a controller in communication with the devices at the well site100). For example, a non-transitory computer readable medium may store instructions on a memory coupled to a processor such that the instructions include functionality for deploying the flapper holder tool300. While the various blocks inFIG.10are presented and described sequentially, one of ordinary skill in the art will appreciate that some or all of the blocks may be executed in different orders, may be combined or omitted; and some or all of the blocks may be executed in parallel. Furthermore, the blocks may be performed actively or passively.

In Block1000, a pressure to the TRSSSV is continuously monitored. For example, various pressure sensors positioned in the wellbore and on the surface may measure an amount of pressure being provided to the TRSSSV. The various pressure sensors transmit the measurements to a controller and/or operator to be monitored.

In Block1001, the measured pressure is compared to predetermined thresholds. For example, the predetermined threshold of the pressure to the TRSSSV may be a value equal to a minimum amount of pressure (for example, a required hydraulic pressure of 4,000-10,000 psi) required to keep the TRSSSV open (i.e., the actuation device is moved to a downward position to displace the flapper to the open position). If the measured pressure has not dropped below the predetermined threshold, this indicates that the TRSSSV is maintained in the open position, thereby allowing downhole operations to be conducted as shown in Block1009. However, if the measured pressure has dropped below the predetermined threshold, this indicates that the TRSSSV has failed (i.e., the actuation device has moved upward no longer engaging the flapper, and the flapper is moved to the closed position). With the TRSSSV indicated as failed, the method moves to the Block1002.

In Block1002, with the TRSSSV indicated as failed, the flapper holder tool with a running/pulling tool is attached to a cable, such as a wireline, slickline, or coiled tubing, and run into the wellbore. For example, the flapper holder tool is placed over an end of the cable outside the wellhead or the BOP such that the cable runs through the flapper holder tool. Additionally, the cable is set within the opening of the flapper holder tool and set screws lock the cable with the flapper holder tool. Furthermore, the running/pulling tool is engaged with internal fish neck of the flapper holder tool.

In Block1003, a zero depth is taken from the crown valve of the wellhead. For example, a depth of the flapper holder tool in the well is taken from the crown valve as the datum.

In Block1004, water is pumped into the wellbore to equalize a pressure above and below the TRSSSV. For example, fresh water may be pumped through the wing valve of the wellhead and into the wellbore and flow through the TRSSSV via the production tubing.

In Block1005, the flapper holder tool is lowered into the wellbore (i.e., RIH) to a depth of the TRSSV and then picked up 10 feet. By picking up 10 feet above the TRSSV, weight is picked up from the running tool and a weight of the tool string is measured. Additionally, the flapper holder tool engages with the TRSSSV. For example, the lip of the flapper holder tool lands within the TRSSSV. In some embodiments, the lip sits above the flapper of the TRSSSV. The lip may seal against a surface in the TRSSSV.

In Block1006, the flapper holder tool is run further downhole to a no-go point. The no-go point is when the lip of the flapper holder tool lands on the TRSSSV. Additionally, at the no-go point, the flapper holder tool is jarred down to shear the running/pulling tool.

In Block1007, pulling out-of-hole operations are started. As the cable is pulled upward, a weight being pulled is measured. The measured weight is compared to the weight of the tool string without the flapper holder tool to ensure that the flapper holder tool has been set on the TRSSSV.

In Block1008, the wellhead pressure is continuously monitored. For example, a pressure gauge at the wellhead may provide continuously readings to confirm the TRSSSV is opened. With the flapper holder tool opening the TRSSSV, the pressure gauge will record an increase in pressure to provide the pressure within the well is back to the pressure with the TRSSSV open.

Now referring toFIGS.11-17, in one or more embodiments,FIGS.11-17illustrate a system of implementing the method described in the flowchart ofFIG.10using the flapper holder tool300ofFIG.3in a well intervention operation.

InFIG.11, in one or more embodiments, a close-up view of the surface102ofFIG.1is illustrated. In a well intervention operation, a cable11is employed from a cable unit10into the wellhead103. The cable unit10may be a truck15or trailer having a drum to spool and unspool the wireline, slickline, or coiled tubing. The cable11may be inserted into the wellhead103via the lubricator207and through the BOP200rigged on top of the wellhead103. The BOP200may include a blind ram to close and seal around the cable11which allows operations to be performed under pressure, on surface equipment, when the cable11is still in the wellbore103. Then the valves of the wellhead103are opened to enable the cable11to fall or be pumped into the wellbore130under pressure.

From the wellhead103, the cable11down a tubular string, such as the production tubing131, and has not passed through the TRSSSV205yet. At an end of the production tubing131below the TRSSSV205may be a bottomhole assembly (BHA)6. the BHA6may include various components such as drill bits, drill collars, mud motors, stabilizers, sensitive measurement equipment, logging while drilling (LWD) tools, measurement while drilling (MWD) tools, and various other downhole tools without departing from the scope of the present disclosure.

FIG.12illustrates a closeup cross-sectional view of the dotted box12ofFIG.11. As previously described, the TRSSSV205makes up a part of the production tubing131. In the case that the pressure system fails, the pressure within the TRSSSV205has dropped allowing the actuation device217to move axially upward and to move the flapper218out of the open position. Without the flapper218in the open position, the flapper218closes a bore the production tubing131thereby not allowing the cable11to pass through the TRSSSV205.

Now referring toFIG.13, as the TRSSSV205has failed, the flapper holder tool300(as described inFIG.3) is deployed to move the flapper (218) back to the open position. The flapper holder tool300is attached to the cable11on the surface102with a running tool220a. For example, the cable11is run through the second end303so that the cable11travels through the bore (306) of the tubular body301, and past the first end302to exit the flapper holder tool300. Additionally, the cable11is set on the one or more ledges (313) of the flapper holder tool300within the opening312(314) that is defined in the bore (309). Further, the plurality of set screws (314) locks the cable11to the flapper holder tool300.

With the flapper holder tool300on the cable11, a zero depth measurement is taken from the crown valve201of the wellhead103to establish a datum for depth measurements with respect to the flapper holder tool300Additionally, a fluid line202amay be attached to the wing valve202of the wellhead103. Through the fluid line202a, a fluid is pumped (see arrow W) into the wellbore130to equalize a pressure above and below the TRSSSV205. For example, the fluid may be fresh water pumped through the wing valve202and into the wellbore130and flow through the TRSSSV205via the production tubing131. Once the pressure is equalized above and below the TRSSSV205, the fluid is no longer pumped into the wellbore130.

In one or more embodiments, pressure between the BOP200and the lubricator is equalized. After equalizing the pressure, the BOP200is opened to allow the flapper holder tool300to be lowered in the wellbore130and land TRSSSV205. For example, the cable11is further lowered to be adjacent or contact the TRSSSV205and the flapper holder tool300is simply dropped down the wellbore130.

FIG.14illustrates a closeup cross-sectional view of the dotted box14ofFIG.13. As previously described, the flapper holder tool300is deployed and lowered down the production tubing131via the cable11to reach the TRSSSV205. Once the flapper holder tool300reaches the TRSSSV205, the cable11is pulled upward (see arrow U1) to pick up the flapper holder tool300a distance D above the TRSSSV205. For example, the distance may be 10 feet such that the flapper holder tool300is not engaged with the TRSSSV205. With the flapper holder tool300lifted above the TRSSSV205, a weight on the cable11holding the flapper holder tool300is measured. The weight on the cable11with the flapper holder tool300hanging thereof is recorded and stored.

Now referring toFIG.15, with the weight on the cable11with the flapper holder tool300measured, the flapper holder tool300is lowered to move the flapper (218) back to the open position. For example, the flapper holder tool300is jarred down to shear off the running tool220aand the lip304of the flapper holder tool300at the first end302lands on the TRSSSV205(i.e., the no-go point). For example, the lip304sits on the second end212(i.e., an upper most end) of the TRSSSV205. From the first end302, the tubular body301extends downward such that the second end303forces that the flapper218to the open position. Additionally, the flapper218is contacting the outer surface308of the tubular body301. In some embodiments, a coating on the outer surface308reduces a friction between the flapper218and the tubular body301.

In one or more embodiments, the cable11may be pulled upward (see arrow U2) and a weight being pulled is measured. The measured weight is then compared to the weight of the cable11with the flapper holder tool300to ensure that the flapper holder tool300has been set on the TRSSSV205(i.e., the measured weight should be less than the weight of the cable11with the flapper holder tool300). It is further envisioned that a pressure gauge at the wellhead (103) may provide continuously readings to confirm the TRSSSV205is opened. For example, if a pressure gauge records an increase in pressure, this indicates that the pressure within the wellbore (130) is returning back to the wellbore pressure when the TRSSSV205open.

Now referring toFIG.16, with the flapper218back in the open position, well intervention operations may continue. For example, the cable11may be lowered (see arrow Dw) through the flapper holder tool300and exit below the TRSSSV205.

Now referring toFIG.17, with the flapper holder tool300landed on the TRSSSV205and moving the flapper218to the open position, a pulling tool220bmay be sent into the wellbore130to retrieve the flapper holder tool300and/or the BHA6. The pulling tool220bmay be lowered into the first end302to engage the internal fish neck311. Once engaged with the internal fish neck311, the pulling tool220bmay be move upward (see block Arrow U) via the cable11to retrieve the flapper holder tool300and/or the BHA6. As the BHA6travels upward, the BHA6will engage the flapper holder tool300. The BHA6and the flapper holder tool300may be raised together to the surface (108) for maintenance, repairs, or replacement.

In case of TRSSSV failure, according to embodiments herein, a method and system for utilizing a flapper holder tool is deployed to open the TRSSSV. By using the flapper holder tool, well control is achieved in the case where the TRSSSV fails. Additionally, using the flapper holder tool according to embodiments herein avoids losing tools downhole and cutting the wireline, slickline, or coiled tubing. Overall, in the case where the TRSSSV fails, using the flapper holder tool to open the TRSSSV may minimize the need for fishing operations and can return the well to service faster to significantly improve the operational safety, reliability, and longevity during drilling, completion, well intervention, and work-over operations.

While the present disclosure has been described with respect to a limited number of embodiments, those skilled in the art, having benefit of this disclosure, will appreciate that other embodiments may be devised which do not depart from the scope of the disclosure as described herein. Accordingly, the scope of the disclosure should be limited only by the attached claims.