Drill hole fluid communication tool

Abstract

borehole fluid communication tool (46), the tool comprising: a housing (100) with a central passage (102) along a longitudinal axis (104), wherein the housing (100) has at least one radial connection (130); a sealing arrangement (106) arranged along the central passage (102) and adjacent to the radial port (130), wherein the sealing arrangement (106) comprises a first housing opening seal (132) arranged on an upstream side of the radial port (130); an outer sleeve arrangement (108) arranged radially inside the housing (100) along the central passage (102), wherein the outer sleeve arrangement (108) has a first door (146) and a second door (148) adjacent to each other to define a door gap (150) in a closed configuration, wherein the door gap (150) is initially positioned upstream of the first housing opening seal (132) of the sealing arrangement (106); an inner mandrel (114) arranged radially within the outer sleeve assembly (108) and having a radial opening (190) initially located on the upstream side of the first housing opening seal (132); and a first seating arrangement (198) which is arranged in the outer sleeve arrangement (108) and is initially coupled with the inner mandrel (114) as well as the first door (146) and the second door (148) of the outer sleeve arrangement (108) to move together axially downstream when a first object (204) is placed in the first seating arrangement (198); wherein the first door (146) is actuated to be disengaged from the first seating arrangement (198), the second door (148) and the inner mandrel (114) when the door gap (150) is moved axially over the first housing opening seal (132) in the closed configuration, so that the second door (148) separates from the first door (146) to define an open configuration of the door gap (150) and to selectively allow fluid communication between the central passage (102) and a location outside the housing (100).

Description

AREA OF REVELATION

[0001] The present disclosure generally relates to well construction. More particularly, the present disclosure relates to systems and methods for utilizing a wellbore fluid completion tool to facilitate a single-pass cementing operation during well construction. GENERAL STATE OF THE ART

[0002] Constructing a well for hydrocarbon production often requires drilling the wellbore to a depth of several hundred to several thousand feet to reach the hydrocarbon-producing zones. Typically, a primary cementing operation can be performed as part of the wellbore construction process. The primary cementing operation is most commonly performed by pumping cement through a tubular string to the bottom of a casing section and then up over a wellbore annulus to create a cement barrier within the wellbore between the casing section and the wellbore wall. The cement barrier can serve a variety of functions, such as preventing fluid communication between the producing zones or protecting the casing section from corrosion by formation fluids.

[0003] Due to the depth at which the casing sections can be installed, the primary cementing operations may require extremely high pressures to force the cement through the tubing string and to the well annulus.

[0004] Such pressures could lead to inadvertent fracture of the bottomhole formation. A common approach to avoid this problem is to drill the wellbore and install the casing in segments, running the tubing string downhole multiple times to complete the primary cementing operation. However, this approach is often considered inefficient from both a time and economic perspective. To address these concerns, a method for communicating with the annulus from the top down was developed.

[0005] WO 2015 / 110 463 A2 relates to a sliding sleeve tool and its use in downhole operations. The sliding tool comprises a tubular housing having one or more flow openings. A first sleeve is slidably connected to the first sleeve and the tubular housing, wherein the first sleeve can be moved from a first position in the wellbore, in which it covers the one or more flow openings, to a second position to expose the one or more flow openings to enable fluid flow between the wellbore and the interior of the tubular housing.

[0006] US 2013 / 0 175 040 A1 relates to a sliding sleeve device consisting of a first sleeve that can be displaced under pressure by a dropped object on a seat to open a housing opening. A second sleeve is aligned with the first sleeve and can be displaced to span the housing openings exposed during the initial displacement of the opening sleeve. Snap rings or other locking devices can be used to hold the locking sleeve in the displaced position, with the housing openings closed.

[0007] US 2013 / 0 048 298 A1 relates to a wellbore servicing device comprising a housing defining an axial flow bore and including openings, a first sleeve, a second sleeve movable relative to the housing from (a) a first position in which the second sleeve blocks fluid communication via the openings of the housing, to (b) a second position in which the second sleeve enables fluid communication via the openings of the housing, and wherein the first sleeve is movable relative to the housing from (a) a first position in which the first sleeve does not allow fluid pressure applied to the axial flow bore to move the second sleeve from the first position to the second position, to (b) a second position in which the first sleeve allows fluid pressure applied to the axial flow bore to move the second sleeve from the first position to the second position, and an expandable seat.

[0008] US 2009 / 0 014 185 A1 relates to an annular throttling mechanism incorporated into a flow path within the outer housing of the sleeve valve to the inner flow ports of the sliding sleeve element. When the sliding sleeve element is moved axially within the housing, the lateral fluid ports of the sliding sleeve element are aligned within specific bore sections, thereby changing the size of the annular space between the fluid ports in the housing and the fluid ports in the sleeve. The annular flow area through the annular space determines the flow rate of the fluid through the valve.

[0009] US 2014 / 0 048 271 A1 concerns a method for testing the reliability of complex systems, which also includes the evaluation and optimization of the availability of such systems. BRIEF DESCRIPTION OF THE DRAWINGS Fig. 1 shows a schematic view of a single pass well cementing operation performed in a wellbore during well construction, according to one or more illustrative embodiments. Fig. 2A shows a cross-sectional view of a first configuration of a closed-hole fluid communication tool used in a single-pass well cementing operation, according to one or more illustrative embodiments. Fig. 2B shows a cross-sectional view of a second configuration of the closed-hole fluid communication tool used in a single-pass well cementing operation, according to one or more illustrative embodiments. Fig. 2C shows a cross-sectional view of the downhole fluid communication tool in an open configuration according to one or more illustrative embodiments. Fig. 2D shows a cross-sectional view of an alternative embodiment of the downhole fluid communication tool in an open configuration according to one or more illustrative embodiments. Fig. 2E shows a cross-sectional view of the wellbore fluid communication tool once closed following completion of the single-pass wellbore cementing operation, according to one or more illustrative embodiments. Fig. Figure 2F shows a cross-sectional view of the wellbore fluid communication tool once sealed with a passageway following completion of the wellbore cementing operation, according to one or more illustrative embodiments. Fig. 3 is a flow diagram illustrating an exemplary method for performing a single pass well cementing operation in a wellbore using the downhole fluid communication tool during well construction. Fig. 4 is a flow diagram illustrating an exemplary method for establishing fluid communication between a tubing string and a wellbore, according to one or more illustrative embodiments. DESCRIPTION OF ILLUSTRATIVE EMBODIMENTS

[0010] Embodiments of the present disclosure relate to using a downhole fluid communication tool to perform a single-pass wellbore cementing operation during the construction of a wellbore. While the present disclosure is described herein with reference to illustrative embodiments for particular applications, it is to be understood that the embodiments are not so limited. Other embodiments are possible, and modifications may be made to the embodiments within the spirit and scope of the teachings herein and in other fields in which the embodiments would be of substantial use.

[0011] The disclosure may repeat reference numerals and / or letters in the various examples or figures. This repetition is for simplicity and clarity and does not, in and of itself, dictate any relationship between the various embodiments and / or configurations discussed. Furthermore, spatially relative terms such as below, under, lower, above, upper, upstream, downstream, and the like may be used herein for convenience of description to describe the relationship of one element or feature to another element(s) or feature(s) as illustrated, wherein the upward direction is understood toward the top of the corresponding figure and the downward direction is understood toward the bottom of the corresponding figure.Unless otherwise noted, the spatially relative terms are intended to encompass different orientations of the device being used or operated in addition to the orientation illustrated in the figures. For example, if a device is turned over in the figures, elements described as being "below" or "under" other elements or features would then be oriented "above" the other elements or features. Accordingly, the exemplary term "under" can encompass both an "above" and "under" orientation. The device may be oriented differently (rotated 90 degrees or with other orientations), and the spatially relative descriptive elements used herein can also be interpreted accordingly.

[0012] As noted above, embodiments of the present disclosure relate to using a downhole fluid communication tool to perform a single-pass well cementing operation during the construction of a wellbore. Although the downhole fluid communication tool is described herein in the context of a well cementing operation, it is contemplated that the downhole fluid communication tool may be used in any application in which a valve may be actuated between closed and open positions and the integrity of the valve seal must be maintained during actuation of the valve. For example, the downhole fluid communication tool may be used as a diverter to equalize pressure within a tubing string and an area outside the tubing string, such as an annulus of a wellbore.Likewise, the wellbore fluid communication tool may be used as a valve in production operations, such as in a production string. In any case, with respect to generalized embodiments used in cementing operations, a system used to perform a single-pass wellbore cementing operation in a wellbore may include a tubing string with a wellbore fluid communication tool, a guide tool for the casing string hanger system, an expandable casing string hanger system, a casing string, and a float assembly.In one embodiment, the downhole fluid communication tool may include: a housing having a central passage therethrough, the housing including at least one radial port between the central passage and a location exterior to the downhole fluid communication tool; a seal assembly disposed along the central passage and adjacent the radial port; an outer sleeve assembly disposed within the housing along the central passage, the outer sleeve assembly including a door assembly having first and second doors adjacent each other to define a door gap, the door gap initially positioned upstream of the seal assembly; an inner mandrel having a radial opening; and a first seat assembly disposed within the outer sleeve assembly and coupled to the inner mandrel.In an additional embodiment, the downhole fluid communication tool may include a second seat assembly.

[0013] With reference to Fig. 1 illustrates a schematic view of a single-pass well cementing operation performed in a wellbore during well construction. Although the single-pass well cementing operation is set forth in an onshore environment, the method and systems described herein may also be implemented in an offshore environment. In certain embodiments, the single-pass well cementing operation may be performed using a cement source 10, such as a cement truck, and a drilling rig 12 at surface 14. The drilling rig 12 may be used to facilitate the installation of a cementing head 16 and a drill bit 18 at the top of a wellbore 20 drilled through a hydrocarbon zone 22.In one embodiment, the cement source 10 may include a cement tank 24, a suction line 26, a cement pump 28, and a supply line 30.

[0014] As further stated in Fig. 1, in certain embodiments, the wellbore 20 may include a partially lined section 32 in which a segment of casing 34 is secured by cement 36, and an open hole section 38 extending to the bottom of the wellbore 20; however, in an alternative embodiment, the wellbore 20 may not include a lined section 32. A tubular string 42 may be run into the wellbore 20 from the surface 14 to a position near the bottom of the wellbore 40. In a preferred embodiment, the tubular string 42 may include segments of drill pipe 44, a downhole fluid communication tool 46, and a float assembly 54. The tubular string 42 may also include a guiding tool for a casing string hanger system 48, an expandable casing string hanger system 50, and a casing string 52. In one or more embodiments, the downhole fluid communication tool 46 may be a cementing tool.In certain embodiments, the float assembly 54 may include a float collar 56 with a backflow prevention valve 58 and a guide shoe 60. The arrangement of the tubing string 42 within the wellbore 20 forms an annulus 62 between the housing 34 and / or a wellbore wall 64 and the tubing string 42. To perform a single-pass wellbore cementing operation 20, the downhole fluid communication tool 46 is positioned at a first location above the float assembly 54, and the float assembly 54 is spaced and positioned below the downhole fluid communication tool 46 on the tubing string 42 within the wellbore 20.

[0015] After placing the tubing string 42 in the wellbore 20, the cementing operation is carried out with a single pass in two phases: a primary cementing operation and a secondary cementing operation, which are carried out with reference to the wellbore fluid communication tool 46 and the Fig. 2A-2F are discussed below. The primary cementing operation begins using the cement pump 28 to draw cement from the cement tank 24 using the suction line 26. The cement pump 28 then delivers cement via the supply line 30 into the cementing head 16. The cementing head 16 injects the cement through the wellhead 18 and the casing string 42, where it exits adjacent the bottom of the well 40 through the guide shoe 60 of the float assembly 54. The injection of cement into the casing string 42 is terminated when the desired region of the wellbore 20 is filled with cement. For example, it may be desirable to cement below the hydrocarbon zone 22 (not shown).Thereafter, in certain embodiments, a wiper plug (not shown) may be inserted through the tubing string 42 to remove any remaining cement until it comes to rest within the float collar 56 of the float assembly 54, effectively sealing the bottom of the casing 52. Subsequently, in some embodiments, a volume of observation fluid 66 is injected through the tubing string 42 to fill the casing 52. The observation fluid 66 preferably has fluid properties that prevent the cement from completely mixing with the observation fluid 66. Thus, the observation fluid 66 preferably settles out of the cement when the cement and observation fluid 66 are disposed in a closed volume.For example, in one embodiment, the observation fluid 66 may have a higher density than the cement used in the single-pass cementing process described herein.

[0016] Fig. Figure 2A shows a cross-sectional view of a first configuration of a closed-hole fluid communication tool 46 extending into the wellbore 20 on the tubing string 42. (See Fig. 1). The term "closed," as used herein with reference to the downhole fluid communication tool 46, indicates that various components of the downhole fluid communication tool 46 are configured to prevent fluid communication between the interior and exterior of the downhole fluid communication tool 46. The downhole fluid communication tool 46 is used to enable the second phase (i.e., the secondary cementing operation) of the single-pass cementing operation in which cement is forced through the

[0017] Wellbore fluid communication tool 46 enters the annulus 62 of the wellbore 20 at a location upstream of the wellbore bottom 40 and flows down to the wellbore bottom 40. Described in another way, the wellbore fluid communication tool 46 enables the introduction of cement into the wellbore 20 during a secondary cementing operation from a location upstream of the location at which cement was introduced into the wellbore 20 during the primary cementing operation. This type of operation contrasts with conventional cementing operations that only resemble the primary cementing operation described herein, which, in a similar configuration, would require injecting cement from the surface 14 through the tubing string 42 within the wellbore 20 and out the guide shoe 60 of the float assembly 54 near the wellbore bottom 40 and the annulus 62 of the wellbore 20 back upstream.Depending on the depth of the wellbore 20, conventional cementing operations require extremely high pressures to circulate the cement back up the annulus 62 of the wellbore 20, which could potentially fracture the hydrocarbon zone 22 or, alternatively, could require multiple cementing passes in the wellbore 20 to minimize the required pressure.

[0018] As in Fig. 2A, the downhole fluid communication tool 46 includes a housing 100 defining a central passage 102 that enables fluid communication with the drill pipe 44 of the tubing string 42 along a longitudinal axis 104. The downhole fluid communication tool 46 may further include a seal assembly 106, an outer sleeve assembly 108, an intermediate casing ring 110, an intermediate casing ring stop 112, and an inner mandrel 114 disposed along the central passage 102.

[0019] As further discussed herein, the downhole fluid communication tool 46 is opened, closed, and sealed by a series of axial movements by the outer sleeve assembly 108 and the inner mandrel 114 within the housing 100 along the longitudinal axis 104.

[0020] In certain embodiments, the housing 100 may include an upper housing portion 116, an intermediate housing portion 118, and a lower housing portion 120; however, in certain embodiments, the housing 100 may be formed as a continuous body. The upper housing portion 116 may include threads 122 for engagement with the drill pipe 44 of the tubing string 42 or the intermediate housing portion 118.

[0021] Although not limited to a particular attachment mechanism, in one or more embodiments, the intermediate housing portion 118 may include threads 124 for engaging the upper housing portion 116 and the lower housing portion 120. The intermediate housing portion 118 further includes a set of one or more first shear pins 126 and a set of one or more second shear pins 128. As discussed in more detail below, the first shear pins 126 engage the outer sleeve assembly 108, and the second shear pins 128 engage the intermediate housing ring 110. The intermediate housing portion 118 further includes one or more radial ports 130. Although in Fig. 2A, it is anticipated that in some embodiments, the intermediate housing portion 118 may include a plurality of radial ports 130 that may be located in multiple planes along the length of the housing 100. The seal assembly 106 is positioned adjacent the radial ports 130. In certain embodiments, the seal assembly 106 may include a first housing port seal 132 and a second housing port seal 134 positioned on opposite sides of the radial ports 130 and sealing between the intermediate housing portion 118 and the outer sleeve assembly 108. The seals may be disposed in seal seats formed in the intermediate housing portion 118 on opposite sides of the ports 130.Although not limited to any particular type of material for the construction of the seal, in one or more embodiments, the seals 132, 134 may be formed from various types of elastomers, including, but not limited to, unsaturated rubbers, saturated rubbers, and thermoplastic elastomers.

[0022] Similar to the upper housing portion 116, the lower housing portion 120 includes threads 122 for engaging the drill pipe 44 of the tubing string 42 and the intermediate housing portion 118, respectively. In some embodiments, the downhole fluid communication tool 46 may include an upper housing seal 136 disposed between the upper housing portion 116 and the intermediate housing portion 118. Additionally, a lower housing seal 138 may be disposed between the lower housing portion 120 and the intermediate housing portion 118.

[0023] In a preferred embodiment, the outer sleeve assembly 108 may include a door assembly 140, a first sleeve collar 142, and a second sleeve collar 144. Further, as discussed further below, the outer sleeve assembly 108 may include a plurality of releasable attachment mechanisms (described below), such as lugs, disposed within the door assembly 140, the first sleeve collar 142, and the second sleeve collar 144. The door assembly 140 may include a first door 146 and a second door 148 positioned adjacent to each other to define a door gap or door joint 150 therebetween. As explained below, in certain configurations of the downhole fluid communication tool 46, the doors 146, 148 are movable relative to each other to change the dimension of the door gap 150, or in other words, to change the distance between the doors 146, 148.When the doors 146, 148 are substantially adjacent to each other or otherwise abut each other, the door gap 150 may be characterized as "narrow," while moving the doors 146, 148 apart increases the spacing of the door gap 150.

[0024] In any event, in a first configuration of the downhole fluid communication tool 46, the door gap 150 is positioned in a narrow configuration between the intermediate housing ring stop 112 and the first housing opening seal 132. The first door 146 may include an upper portion 152, a first releasable attachment mechanism 154, such as a first set of lugs, and a lower portion 156. Similarly, the second door 148 may include an upper portion 158, a second releasable attachment mechanism 160, such as a second set of lugs 160, and a lower portion 162. When the downhole fluid communication tool 46 is in a first closed configuration, the lugs 154 and 160 are biased toward and engaged with the inner mandrel 114 by a spring or other biasing mechanism known to those skilled in the art.Additionally, the shear pins 126 engage the upper portion 152 of the first door 146 of the door assembly 140.

[0025] In one embodiment, the first sleeve collar 142 and the second sleeve collar 144 may each be positioned axially spaced from the door assembly 140. The first sleeve collar 142 may include a base 164 having a third releasable attachment mechanism, such as a third set of lugs 166 biased toward the inner mandrel 114 by a spring or other biasing mechanism, as known to those skilled in the art. In one embodiment, the lugs may be biased by a tension spring inserted into a groove formed on the outer diameter of the lug 166. The first sleeve collar 142 may further include a crown 168 having a shoulder 170 defined therein. Additionally, a ring 172 may be defined between the crown 168 of the first sleeve collar 142 and the inner mandrel 114.The second sleeve collar 144 may also include a base 174 that receives a fourth releasable attachment mechanism, such as a fourth set of lugs 176 biased toward the inner mandrel 114 by a spring or other biasing mechanism known to those skilled in the art. The second sleeve collar 144 may further include a crown 178 having a flange 180 secured to the lower housing portion 120. Similar to the first sleeve collar 142, a ring 182 may be defined between the crown 178 of the second sleeve collar 144 and the inner mandrel 114. In one embodiment, the crown 178 and the base 174 of the second sleeve collar may be engaged using threads 122, 124. However, in other embodiments, the crown 178 and the base 174 may be formed as a continuous body.

[0026] With continued reference to Fig. 2A, the inner mandrel 114 includes an upper end 184, a lower end 186, a passage 188 in fluid communication with the central passage 102, one or more radial openings 190, an outer profile 192 containing one or more grooves 194, and a lower mandrel shoulder 196 disposed substantially within the outer sleeve assembly 108. Although a set of radial openings 190 in Fig. 2A, it is anticipated that in some embodiments, the inner mandrel 114 may include one or more openings 190 arranged in one or more sets of radial openings 190. In certain embodiments, the plurality of grooves 194 on the outer profile 192 includes a first mandrel groove 194a, a second mandrel groove 194b, a third mandrel groove 194c, and a fourth mandrel groove 194d. In the first closed configuration of the downhole fluid communication tool 46, the lugs 154 engage the first mandrel groove 194a, which is radially aligned with the intermediate housing ring 110. The lugs 160 engage the second mandrel groove 194b, which is positioned directly below the second housing opening seal 134. The third mandrel groove 194c is positioned between the lower portion 162 of the second door 148 and the crown 168 of the first sleeve collar 142.Finally, the fourth mandrel groove 194d and the lower mandrel shoulder 196 are positioned in the ring 182 of the second sleeve collar 144.

[0027] The wellbore fluid communication tool 46 may further include a first seat assembly 198 having an object seat 202 positioned near the upper end 184 of the inner mandrel 114. In one or more embodiments, the seat assembly 198 may also include an upper lip 200 adjacent the object seat 202. Furthermore, the object seat 202 may be extrudable. In an alternative embodiment, discussed further herein, the wellbore fluid communication tool 46 may include an additional seat assembly (not shown). In certain embodiments, the first seat assembly 198 may be engaged with the upper end 184 of the inner mandrel 114 using threads 122, 124.

[0028] Now, with regard to Fig. 2B illustrates a cross-sectional view of a second configuration of the closed-hole fluid communication tool 46. In this second configuration, the closed door assembly 140 has been translated toward the first sleeve collar 142, with the narrow door gap 150 translated over the first casing port seal 132. Translating the door assembly 140 over the seal assembly 106 to a closed position prevents damage to the seal assembly 106 from occurring. As discussed above, the first casing port seal 132 and the second casing port seal 134 may be constructed of elastomeric materials that are subject to deterioration due to shear stresses.Because the door assembly 140 includes a narrow door gap 150 in a closed position, the area between the first and second doors 146, 148 is relatively small, resulting in fairly smooth sliding over the first housing opening seal 132 and the second housing opening seal 134. In contrast, similar tools require open holes with larger areas to slide over an elastomeric seal, potentially creating a frictional effect on the seal. This frictional effect can, over time, compromise the integrity of the seal and the functionality of the tool.

[0029] To transition the downhole fluid communication tool 46 from the first closed configuration to the second closed configuration, a first object 204 is deposited onto the seat 202 of the first seat assembly 198. As used herein, the first object 204 may be any device that is dropped or pumped down a wellbore for depositing onto the seat 202, including, but not limited to, balls, darts, or other objects. In either case, the tubing string 42 is pressurized, and pressure is applied to the first object 204 through the central passage 102. A buildup of pressure uphole from the first object 204 results in axial displacement of the door assembly 140, the first seat assembly 198, and the inner mandrel 114.Initially, the pressure buildup on the upstream side of the first object 204 causes the shear pins 126 to shear from the upper portion 152 of the first door 146, allowing the upper portion 152 of the first door 146 to axially translate 118 the intermediate housing portion downward until an outer shoulder 206 of the upper portion 152 of the first door 146 engages the intermediate housing ring 110. This movement allows the door gap 150, in its narrow configuration, to move over the first housing port seal 132 and the lower portion 162 of the second door 148 to enter the ring 172 of the first sleeve collar 142. Once the upper portion 152 of the first door 146 engages the intermediate housing ring 110, the lugs 154 release the first mandrel groove 194a, allowing the inner mandrel 114 to translate downward.This downward movement causes the radial openings 190 to be displaced toward the radial ports 130 of the intermediate housing section 118, the second mandrel groove 194b to be displaced toward the crown 168 of the first sleeve collar 142, the third mandrel groove 194c to be displaced toward the crown 168 of the first sleeve collar 142, the fourth mandrel groove 194d to be displaced further into the crown 178 of the second sleeve collar 144, and the lower mandrel shoulder 196 to be displaced into the base 174 of the second sleeve collar 144. The engagement of the lugs 160 in the second mandrel groove 194b prevents further displacement of the inner mandrel 114 within the central passage 102.

[0030] In Fig. Figure 2C illustrates a diagram of the downhole fluid communication tool 46 in an open configuration. To open the downhole fluid communication tool 46, additional pressure is applied through the tubing string 42 and the central passage 102 to the first object 204. This pressure results in a downward force on the inner mandrel 114, displacing the inner mandrel 114 further into the central passage 102, resulting in the radial alignment of the radial openings 190 of the inner mandrel 114 and the radial ports 130 of the intermediate housing section 118. In embodiments having a lip 200, the upper lip 200 of the first seat assembly 198 engages the inner mandrel 114.This downward movement of the inner mandrel 114 causes the second mandrel groove 194b to engage and exert a force on the lugs 160, which in turn exert a downward force on the upper portion 158 and lower portion 162 of the second door 148, which displaces the lower portion 162 of the second door 148 into the ring 172 of the first sleeve collar 142 until it rests against the shoulder 170 within the crown 168 of the first sleeve collar 142. Once the lower portion 162 of the second door 148 engages the shoulder 170 of the first sleeve collar 142, the distance of the door gap 150 is at full extension, effectively opening the door assembly 140 of the downhole fluid communication tool 46 and providing a fluid communication path "F" through the tubing string 42, the central passage 102, the radial openings 190 and the radial ports 130 in the intermediate housing portion 118 to the annulus 62 of the wellbore 20.When the second door 148 has engaged the shoulder 170 of the first sleeve collar 142, the fourth mandrel groove 194d has transitioned further into the crown 178 of the second sleeve collar 144, and the lower mandrel shoulder 196 has shifted beyond the lugs 176, allowing the lugs 176 to collapse to a primary outer diameter "OD" of the outer profile 192 of the inner mandrel 114. This primary outer diameter "OD" is defined on the outer profile 192 between the upper end 184 and the lower mandrel shoulder 196 of the inner mandrel 114. This configuration prevents undesirable upward movement of the inner mandrel 114, which would close the door assembly 140 and block the fluid communication path "F," because the engagement of the lugs 176 and the lower mandrel shoulder 196 prevents upward translation of the inner mandrel 114.

[0031] As discussed above, when the downhole fluid communication tool 46 is in an open configuration, the second phase of the cementing application can be implemented with a single pass. Once the door assembly 140 of the downhole fluid communication tool 46 is opened, the pressure in the tubing string 42 can be increased to extrude the first object 204 from the first seat assembly 198. Cement is then injected from the cementing head 16 through the tubing string 42 and into the downhole fluid communication tool 46. As described with reference to Fig. 1, the sealed float assembly 54 and the monitoring fluid 66 previously pumped into the casing string 52 act as a barrier that forces the cement to move through the radial ports 130 of the intermediate casing section 118 and down into the annulus 62 of the wellbore 20.

[0032] In an alternative embodiment, as in Fig. 2D, the downhole fluid communication tool 46 includes a second seat assembly 208 having a seat 210 disposed at the lower end 186 of the inner mandrel 114. Except for the second seat assembly 208, this alternative embodiment of the downhole fluid communication tool 46 includes the same features as previously described with reference to Fig. 2A-2C. In operation, once the door assembly 140 of the well communication tool 46 has been opened, the first object 204 is extruded from the first seating assembly 198 and deposited within the second seating assembly 208. Instead of the monitoring fluid 66 preventing the cement from entering the casing string 52, the second seating assembly 208, along with the first object 204 deposited therein, is used as a barrier that forces the cement to move through the plurality of radial ports 130 of the intermediate casing section 118 and down into the annulus 62 of the wellbore 20. Once the secondary cementing operation is complete, in certain embodiments, pressure is increased through the tubing string 42 and within the central passageway 102 to extrude the first object 204 from the second seating assembly 208.

[0033] Fig. 2E shows a cross-sectional view of a downhole fluid communication tool 46 that has been closed after completion of the single-passage well cementing operation, according to one or more illustrative embodiments. To close the downhole fluid communication tool 46, a second object 212, which in certain embodiments may be larger than the first object 204, is seated in the object seat 202 of the first seat assembly 198. The tubing string 42 is repressurized, and pressure is applied to the second object 212 through the central passage 102. The uphole pressure on the second object 212 results in the second shear pins 128 shearing off the intermediate casing ring 110, causing the intermediate casing ring 110 to move downward.This movement allows the lower portion 156 of the first door 146 to move over the plurality of radial ports 130 of the intermediate housing portion 118 until they mate with the upper portion 158 of the second door 148, thereby forming the narrow door gap 150 of the door assembly 140 between the plurality of radial ports 130 and the second housing port seal 134 and effectively closing the door assembly 140.

[0034] The shearing of the second shear pins 128 from the intermediate housing ring 110 also results in further downward displacement of the first seating assembly 198 and the inner mandrel 114 within the central passage 102. The pressure built up against the second object 212 causes the first seating assembly 198 to exert a downward force on the inner mandrel 114, such as via the upper lip 200. This force causes the second mandrel groove 194b to disengage the lugs 160 in the second door 148, thereby urging the lugs 160 radially toward the crown 168 of the first sleeve collar 142 and allowing further downward displacement of the second mandrel groove 194b, the third mandrel groove 194c, the fourth mandrel groove 194d, and the lower mandrel shoulder 196. This further downward displacement leads to the collapsing and seating of the lugs 166 in the third mandrel groove 194c.In addition, this displacement causes the fourth mandrel groove 194d to move further within the crown 178 of the second sleeve collar 144 and the lower mandrel shoulder 196 to be positioned outside the second sleeve collar 144.

[0035] Fig. Figure 2F shows a cross-sectional view of the downhole fluid communication tool 46 once it has been sealed with a passageway following completion of the well cementing operation. To seal the door assembly 140 of the downhole fluid communication tool 46, additional pressure is applied to the second object 212, which was previously deposited in the object seat 202 of the first seat assembly 198. This pressure causes the first seat assembly 198 to exert a downward force on the first door 146 and the inner mandrel 114, for example, via the upper lip 200. This downward force causes the upper portion 152 of the first door 146 to push the intermediate housing ring 110 downward until it engages the intermediate housing ring stop 112, which further results in the displacement of the narrow door gap 150 over the second housing interface seal 134 and the displacement of the base 164 of the first sleeve collar 142 into the crown 178 of the second sleeve collar 144.The displacement of the base 164 of the first sleeve collar 142 into the crown 178 of the second sleeve collar 144 is further enabled by the lugs 166 sitting in the third mandrel groove 194c, as described with respect to FIG. Fig. 2E. In addition, the downward force described above causes the inner mandrel 114 to slide further within the central passage 102, allowing the lugs 176 to be inserted into the fourth mandrel groove 194d.

[0036] Once the wellbore fluid communication tool 46 has been sealed, in certain embodiments, further pressure may be applied to the second object 212 to extrude it from the first seating assembly 198. The second object 212 may be extruded and used to actuate any number of tools downstream on the tubing string 42. For example, the second object 212 may be incorporated into the guide tool for the casing string hanger system 48 for use in adjusting the expandable casing string hanger system 50, as described with respect to Fig. 1 described, be discontinued.

[0037] With reference to Fig. 3, a flow diagram of an exemplary method 300 for performing a single-pass cementing operation in the wellbore 20 is described. Although the cementing operation need not be limited to specific locations in the wellbore 20, in one or more embodiments, the operations may be performed above and below a hydrocarbon zone 22 during construction of the wellbore 20 using the downhole fluid communication tool 46.

[0038] The method 300 begins in step 302 by running a tubing string 42, including segments of drill pipe 44, a closed-loop downhole fluid communication tool 46, and a float assembly 54, into the wellbore 20 drilled through a hydrocarbon zone 22. The tubing string may also include a guiding tool for the casing string hanger system 48, an expandable casing string hanger system 50, and a casing string 52. In preferred embodiments of the method, the downhole fluid communication tool 46 is positioned at a first location in the wellbore 20. The first location is spaced from a second location that is downstream or in-hole from the first location. In preferred embodiments, when the fluid communication tool 46 is at the first location, the float assembly 54 is at the second location, which may be adjacent the bottom 40 of the wellbore 20.The first location may be above the hydrocarbon zone 22, and the float assembly 54 is positioned at the second location, namely at a position below the hydrocarbon zone 22. In other embodiments, the downhole fluid communication tool 46 may be positioned anywhere along a wellbore 20 as desired. More generally, the downhole fluid communication tool 46 as described herein need not be used only in cementing operations, but may be used in any operation where it is desirable to establish fluid communication between the interior of the tubing string 42 and an annulus 62 around the tubing string 42.

[0039] After the tubular string 42 has been positioned in the wellbore 20 at the first location, a primary cementing operation is performed at the second location in step 304 by flowing cementing fluids through the tubular string 42 to a location below the hydrocarbon zone 22. The primary cementing operation begins using a cement pump 28 to discharge cement into a cementing head 16 located at the surface 14. The cementing head 16 injects the cement through the tubular string 42, where it exits through a guide shoe 60 of the float assembly 54 onto the wellbore bottom 40. The injection of cement into the tubular string 42 is terminated when the desired region of the wellbore 20 below the hydrocarbon zone 22 is filled with cement.Thereafter, in embodiments, a wiper plug may be inserted through tubing string 42 to remove any remaining cement until it stops in a float collar 56 of float assembly 54, effectively sealing the bottom of casing 52. In some embodiments, a volume of monitoring fluid 66 is injected through tubing string 42 to fill casing 52.

[0040] In step 306, a door assembly 140 of the downhole fluid communication tool 46 is opened to the annulus 62 of the wellbore 20. In a preferred embodiment, the downhole fluid communication tool 46 includes a housing 100 containing a central passage 102, the housing 100 including one or more radial ports 130 that enable fluid communication between the central passage 102 and a location external to the housing 100, such as the annulus 62 of the wellbore 20.The wellbore fluid communication tool 46 is disposed along the central passage 102 and further includes a seal assembly 106; an outer sleeve assembly 108 having a door assembly 140 operable to move over the seal assembly 106 in a closed position and a plurality of lugs (154, 160, 166, and 176); an inner mandrel 114 having one or more radial openings 190 and a plurality of grooves 194a-194d; and a first seat assembly 198 disposed within the outer sleeve assembly 108 and coupled to the inner mandrel 114.

[0041] To initiate the opening of the door assembly 140 of the downhole fluid communication tool 46, the downhole fluid communication tool 46 must be transitioned from a first closed configuration to a second closed configuration. In the first closed configuration of the downhole fluid communication tool 46, the doors 146, 148 abut or are substantially close to each other such that the door gap 150 is in its narrow configuration and movement of the door assembly 140 relative to the housing 100 is prevented by a first releasable locking mechanism, such as a shear pin 126. To begin the transition, a first object 204 is deposited within the first seating assembly 198, and a first pressure is applied to the first object 204 via the tubing string 42 and the central passageway 102.In certain embodiments, the first object 204 may be dropped or pumped from the surface; however, it is contemplated that the first object 204 may also be deployed from a downhole location using an object dropping tool (not shown) disposed along the tubing string 42.

[0042] Nonetheless, the pressure applied to the first object 204 causes the first releasable locking mechanism, i.e., the first shear pins 126, to shear. The continued downward force applied to the closed door assembly 140 causes the closed door assembly 140, and in particular the first and second doors 146, 148, to be collectively displaced downwardly in an axial direction in their abutting position until the outer sleeve 108 engages the intermediate housing ring 110. In particular, the first shear pin 126 is selected to shear upon application of a first force exerted by the first pressure. In any event, the axial movement of the door assembly 140 causes the door gap 150 in its narrow configuration, ie when the doors 146, 148 are abutting or substantially close to each other, to be displaced over a first housing opening seal 132 of the seal assembly 106.In other words, the doors 146, 148 slide or move together, and the door gap 150 passes over the first enclosure opening seal 132. Because the doors 146, 148 slide together in a closed position, damage to the first enclosure opening seal 132 from the door gap 150 is minimized. Once this occurs, the lugs 154 in the closed door assembly 140 are disengaged from the first mandrel groove 194a of the inner mandrel 114, allowing further downward translation of the inner mandrel 114 and the first seat assembly 198 into the central passageway 102.

[0043] To open the door assembly 140 of the downhole fluid communication tool 46, a second pressure, which may be higher, lower, or equal to the first pressure, is applied to the first object 204, causing the first seat assembly 198 to exert a downward force on the inner mandrel 114. Under this force, the inner mandrel 114 is further displaced along the central passage 102 to a position where the openings 190 of the inner mandrel 114 are aligned with the radial openings 130 of the housing 100. This downward movement of the inner mandrel 114 also causes the second mandrel groove 194b to engage and exert a force on the lugs 160 of the door assembly 140, which in turn exerts an axial downward force on the second door 148 and causes the second door 148 to slide downwardly, one at a time, away from the first door 146.Specifically, the second door 148 is displaced into the annulus 172 of the first sleeve collar 142, thereby widening the door gap 150, effectively opening the door assembly 140 of the downhole fluid communication tool 46 and providing a fluid communication path "F" between the tubing string 42, the central passage 102, the radial openings 190 in the inner mandrel 114, and the radial ports 130 in the housing 100 to the annulus 62 of the wellbore 20. In one or more embodiments, with the application of the second pressure, the displacement of the inner mandrel 114 and the second door 148 occurs simultaneously in this step, such that the port 130 and opening 190 are aligned, while the second door 148 simultaneously displaces or moves away from the first door 146.As discussed above, the second pressure may be greater than, equal to, or less than the first pressure, it being understood that the inner mandrel 114 may translate after shearing the pin 126 using less pressure than is required to shear the pin 126.

[0044] Once the downhole fluid communication tool 46 is in an open configuration, a secondary cementing operation may be performed through the open downhole fluid communication tool 46 above the hydrocarbon zone 22 or the site of the primary cementing operation at step 308 by directing cementing fluids through the aligned port 190 and the port 130 to deliver cementing fluids to the annulus around the downhole fluid communication tool 46. In one or more embodiments, to begin the secondary cementing operation, the pressure within the tubing string 42 is increased to propel or otherwise extrude the offset first object 204 from the first seating assembly 198. Cement is then injected from the cementing head 16 through the tubing string 42 and into the downhole fluid communication tool 46.As discussed with reference to step 302, the sealed float assembly 54 and the monitoring fluid 66 previously pumped through the tubing string 42 and into the casing string 52 serve as a barrier that forces the cement to move through the radial ports 130 of the casing 100 and down into the annulus 62 of the wellbore 20.

[0045] In an alternative embodiment, the downhole fluid communication tool 46 includes a second seating assembly 208 disposed at the lower end 186 of the inner mandrel 114. Except for the second seating assembly 208, this alternative embodiment of the downhole fluid communication tool 46 includes the same features as previously described with reference to steps 302-306. In operation, once the door assembly 140 of the downhole communication tool 46 has been opened, the first object 204 is extruded from the first seating assembly 198 and deposited into the second seating assembly 208. Instead of the observation fluid 66 preventing the cement from entering the casing string 52, the second seat assembly 208, along with the first object 204 disposed therein, is used to force the cement to move through radial ports 130 of the intermediate casing section 118 and down into the annulus 62 of the wellbore 20.

[0046] In step 310, the downhole fluid communication tool 46 is closed to the annulus 62 of the wellbore 20. To close the downhole fluid communication tool 46, a second object 212, which in certain embodiments is larger than the first object 204, is seated in the first seating assembly 198. The tubing string 42 is repressurized, and pressure is applied to the second object 212 through the central passage 102.The uphole pressure on the second object 212 results in the second shear pins 128 shearing from the intermediate housing ring 110, causing the downward movement of the intermediate housing ring 110, which allows the first door 146 to move over the plurality of radial ports 130 of the housing 100 until they mate with the second door 148, thereby driving the door gap 150 into a "tight" configuration and forming the door gap 150 of the door assembly 140 between the radial ports 130 and the second housing port seal 134, and effectively closing the door assembly 140 of the downhole fluid communication tool 46.

[0047] In step 312, the downhole fluid communication tool 46 is sealed. To seal the door assembly 140 of the downhole fluid communication tool 46, additional pressure is applied to the second object 212 previously deposited within the first seat assembly 198. This pressure causes the first seat assembly 198 to exert a downward force on the first door 146 and the inner mandrel 114. In certain embodiments, the downward force is transmitted via an upper lip 200 of the seat assembly 198. This downward force causes the first door 146 to push the intermediate housing ring 110 downward until it engages the intermediate housing ring stop 112, which further results in the displacement of the narrow door gap 150 over the second housing port seal 134 and the displacement of the first sleeve collar 142 into the second sleeve collar 144, effectively sealing the door assembly of the downhole fluid communication tool 46.

[0048] Finally, in step 314, once the downhole fluid communication tool is sealed, in certain embodiments, the expandable casing hanger system 50 may be deployed into the wellbore 20. To set the expandable casing hanger system 50, further pressure may be applied to the second object 212 through the tubing 42 and the central passageway 102 to extrude or otherwise propel it out of the first seating assembly 198. The second object 212 may then be deposited within the casing hanger system guiding tool 48 for use in setting the expandable casing hanger system 50 within the wellbore 20.

[0049] With reference to Fig. 4, a flow diagram illustrating an exemplary method 400 for establishing fluid communication between a tubing string 42 and a wellbore 20 is described.

[0050] The method 400 begins in step 402 by positioning a downhole fluid communication tool 46 in a wellbore 20. In certain embodiments, this may be achieved by running a tubing string 42, including segments of drill pipe 44 and a downhole fluid communication tool 46, into the wellbore 20 in a first closed configuration. In the first closed configuration of the downhole fluid communication tool 46, the doors 146, 148 are abutting or substantially proximate each other such that the door gap 150 is in its narrow configuration and movement of the door assembly 140 relative to the housing 100 is prevented by a first releasable locking mechanism, such as a shear pin 126.Depending on the extent of the downhole operation, the closed borehole fluid communication tool 46 may be positioned at any location along the tubing string 42 where fluid communication with the wellbore 20 is desired.

[0051] In step 404, a first pressure is applied to the downhole fluid communication tool 46 to cooperatively displace a substantially abutting first and second doors 146, 148 of the tool over a first casing opening seal 132. Once the downhole fluid communication tool 46 is positioned at a desired location within the wellbore 20, a first object 204 is seated within the first seating assembly 198, and pressure is applied against the first object 204 via the tubular string 42 and the central passageway 102. In certain embodiments, the first object 204 may be dropped or pumped from the surface; however, it is contemplated that the first object 204 may also be deployed from a downhole location using an object dropping tool (not shown) disposed along the tubing string 42.

[0052] Nonetheless, the pressure applied to the first object 204 causes the first releasable locking mechanism, i.e., the shear pins 126, to shear. The continued downward force applied to the closed door assembly 140 causes the closed door assembly 140, and in particular the first and second doors 146, 148, to be collectively displaced downwardly in an axial direction in their abutting position until the outer sleeve 108 engages the intermediate housing ring 110. In particular, the first shear pin 126 is selected to shear upon application of a first force exerted by the first pressure. In any event, the axial movement of the door assembly 140 causes the door gap 150 in its narrow configuration, ie, when the doors 146, 148 are abutting or substantially close to each other, to be displaced over the first housing opening seal 132 of the seal assembly 106.In other words, the doors 146, 148 slide or move together, and the door gap 150 passes over the seal 132. Because the doors 146, 148 slide together in a closed position, damage to the first enclosure opening seal 132 from the door gap 150 is minimized. Once this occurs, the lugs 154 in the closed door assembly 140 are disengaged from the first mandrel groove 194a of the inner mandrel 114, allowing further downward translation of the inner mandrel 114 and the first seat assembly 198 into the central passageway 102.

[0053] In step 406, the downhole fluid communication tool 46 is opened to the annulus 62 of the wellbore 20 by applying a second pressure to the downhole fluid communication tool 46 to align at least one radial port 130 with at least one internal opening 190 of the downhole fluid communication tool 46 and to move the second door 148 away from the first door 146, thereby establishing fluid communication between the radial port 130, the internal opening 190, and the annulus 62 of the wellbore 20.

[0054] To begin this process as described above, the second pressure, which may be higher, lower, or equal to the first pressure, is applied to the first object 204, causing the first seat assembly 198 to exert a downward force on the inner mandrel 114. Under this force, the inner mandrel 114 is further translated along the central passage 102 to a position where the openings 190 of the inner mandrel 114 are aligned with the radial openings 130 of the housing 100. This downward movement of the inner mandrel 114 also causes the second mandrel groove 194b to engage and exert a force on the lugs 160 of the door assembly 140, which in turn exerts a downward axial force on the second door 148 and causes the second door 148 to translate downwardly, individually translating away from the first door 146.Specifically, the second door 148 is displaced into the annulus 172 of the first sleeve collar 142, thereby widening the door gap 150, effectively opening the door assembly 140 of the downhole fluid communication tool 46 and providing a fluid communication path "F" between the tubing string 42, the central passage 102, the radial openings 190 in the inner mandrel 114, and the radial ports 130 in the housing 100 to the annulus 62 of the wellbore 20. In one or more embodiments, with the application of the second pressure, the displacement of the inner mandrel 114 and the second door 148 occurs simultaneously in this step, such that the port 130 and opening 190 are aligned, while the second door 148 simultaneously displaces or moves away from the first door 146.As previously discussed, the second pressure may be greater than, equal to, or less than the first pressure, it being understood that the inner mandrel 114 may translate after shearing the pin 126 using less pressure than is required to shear the pin 126.

[0055] Thus, a wellbore fluid communication tool is described. Embodiments of the tool may include a housing having a central passage therethrough along a longitudinal axis, the housing including at least one radial port; a seal assembly disposed along the central passage and adjacent the radial port; an outer sleeve assembly disposed within the housing along the central passage, the sleeve assembly having first and second doors adjacent each other to define a door gap, the door gap initially positioned upstream of the seal assembly; an inner mandrel having a radial opening, the inner mandrel being operable to selectively engage the outer sleeve assembly through a plurality of grooves and a lower mandrel shoulder disposed on an outer profile of the inner mandrel;and a first seat assembly disposed within the outer sleeve assembly and coupled to the inner mandrel;

[0056] In the above embodiment, the downhole fluid communication tool may further include any of the following elements, alone or in combination: a housing intermediate ring removably attached to the housing and spaced from a shoulder defined on the outer sleeve. a first releasable locking mechanism arranged to lock the housing and the outer sleeve together, and a second releasable locking mechanism arranged to lock the intermediate housing ring to the housing.

[0057] The seal assembly further comprising a first housing opening seal and a second housing opening seal disposed on opposite sides of the radial opening. the outer sleeve assembly further comprising a first sleeve collar and a second sleeve collar positioned below the first door and the second door. the second sleeve collar, attached to the housing.

[0058] The first sleeve collar, slidable around the inner mandrel under the second door and arranged above the second sleeve collar. the outer sleeve assembly further comprising a plurality of lugs operable to selectively engage the plurality of grooves and the lower mandrel shoulder of the inner mandrel. a second seating arrangement disposed within the inner mandrel near the lower mandrel shoulder.

[0059] Additionally, an alternative embodiment of a downhole fluid communication tool is described herein. Such an embodiment may include a housing having a central passage extending between a first end and a second end and defined along a longitudinal axis, the housing including at least one radial port; a seal assembly disposed along the housing along the central passage between the radial port and the first end of the housing; an outer sleeve assembly disposed within the housing along the central passage, the sleeve assembly having first and second doors adjacent each other to define a door gap, the door gap positioned between the seal assembly and the first end of the housing when the first and second doors are in a first closed position;an inner mandrel having a radial opening, the inner mandrel being disposed within the outer sleeve assembly such that the radial opening is adjacent the door gap, the inner mandrel having a plurality of grooves defined therein; a first releasable fastening mechanism extending from the outer sleeve assembly for engaging a groove of the inner mandrel to secure the inner mandrel to the outer sleeve assembly in the first position; and a first seat assembly disposed within the outer sleeve assembly and coupled to the inner mandrel, the outer sleeve assembly and the inner mandrel being slidable within the housing to a second position when the first releasable locking mechanism is released.

[0060] In the above embodiment, the downhole fluid communication tool may further include any of the following elements, alone or in combination: The outer sleeve assembly includes a shoulder, and the downhole fluid communication tool further includes an intermediate housing ring secured to the housing by a second releasable locking mechanism, the housing ring being spaced from the outer sleeve shoulder when the tool is in the first position.

[0061] The first releasable locking mechanism is a shear pin.

[0062] A sealing arrangement is arranged along the housing on opposite sides of the radial port.

[0063] The outer sleeve assembly further includes a first sleeve collar and a second sleeve collar positioned below the first door and the second door.Thus, there is described herein a method of performing cementing operations in a wellbore, the method comprising positioning a cementing tool in a wellbore at a first location spaced from a second location located downstream of the first location; following cementing operations at the second location, applying a first pressure to the cementing tool to collectively displace a substantially abutting first and second door over a seal of the cementing tool; applying a second pressure to the cementing tool to (i) align an opening of the cementing tool with a port of the cementing tool and (ii) individually displace the second door away from the first door, thereby establishing fluid communication between the opening and the port; and performing cementing operations at the second location.

[0064] In the above embodiment, the method may include any of the following steps, alone or in combination: Performing cementing operations at the second location includes directing cementing fluids through the aligned port and opening to deliver cementing fluids to an annulus around the cementing tool.

[0065] Applying the first pressure by placing an object on a seat in the cementing tool and applying pressure to the object until a shear mechanism bursts and the first and second doors can be moved together.

[0066] Performing cementing operations at the second location includes driving the deployed object from a seat and directing cementing fluids through the seat to the aligned opening and port.

[0067] Thus, there is described herein a method of establishing fluid communication in a wellbore, the method comprising: positioning a downhole fluid communication tool in a wellbore; Applying a first pressure to the tool to cooperatively displace substantially abutting first and second doors of the tool over a seal; and applying a second pressure to the wellbore fluid communication tool to (i) align an outer opening of the tool with an inner port of the tool and (ii) move the second door away from the first door, thereby establishing fluid communication between the opening and the port.

[0068] For the above embodiment, the method may include the following step: Applying the first pressure by placing an object on a seat of the tool and applying the first pressure to the object until a shear pin releases the first and second doors from a first closed position so that the doors can move together to a second closed position.

[0069] The above-mentioned specific embodiments are not intended to limit the scope of the claims. The embodiments may be modified by adding, removing, or combining one or more features or functions described in the disclosure.

Claims

[1] A wellbore fluid communication tool (46), the tool comprising: a housing (100) having a central passage (102) along a longitudinal axis (104), the housing (100) having at least one radial port (130); a seal assembly (106) disposed along the central passage (102) and adjacent the radial port (130), the seal assembly (106) including a first housing opening seal (132) disposed on an upstream side of the radial port (130); an outer sleeve assembly (108) disposed radially inwardly of the housing (100) along the central passage (102), the outer sleeve assembly (108) having a first door (146) and a second door (148) adjacent to each other to define a door gap (150) in a closed configuration, wherein the door gap (150) is initially positioned upstream of the first housing opening seal (132) of the seal assembly (106); an inner mandrel (114) disposed radially inward of the outer sleeve assembly (108) and having a radial opening (190) initially disposed on the upstream side of the first housing opening seal (132); and a first seat assembly (198) disposed within the outer sleeve assembly (108) and initially coupled to the inner mandrel (114) and the first door (146) and the second door (148) of the outer sleeve assembly (108) for axially downstream movement together when a first object (204) is deposited within the first seat assembly (198); wherein the first door (146) is operable to be disengaged from the first seat assembly (198), the second door (148), and the inner mandrel (114) when the door gap (150) in the closed configuration is moved axially over the first housing opening seal (132) such that the second door (148) separates from the first door (146) to define an open configuration of the door gap (150) and selectively enable fluid communication between the central passageway (102) and a location exterior to the housing (100). [2] The downhole fluid communication tool (46) of claim 1, further comprising an intermediate housing ring (110) removably secured to the housing (100) and spaced from a shoulder defined on the outer sleeve assembly (108). [3] The wellbore fluid communication tool (46) of claim 2, wherein the housing (100) further comprises a first releasable locking mechanism arranged to lock the housing (100) and the outer sleeve assembly (108) together, and a second releasable locking mechanism arranged to lock the intermediate housing ring (110) to the housing (100). [4] The downhole fluid communication tool (46) of claim 1, wherein the seal assembly (106) further comprises a second housing port seal (134), and wherein the second housing port seal (134) and the first housing port seal (132) are disposed on opposite sides of the radial port (130). [5] The wellbore fluid communication tool (46) of claim 1, wherein the outer sleeve assembly (108) further comprises a first sleeve collar (142) and a second sleeve collar (144) positioned below the first door (146) and the second door (148). [6] The downhole fluid communication tool (46) of claim 5, wherein the second sleeve collar (144) is secured to the housing (100). [7] The wellbore fluid communication tool (46) of claim 5, wherein the first sleeve collar (142) is slidably disposed around the inner mandrel (114) below the second door (148) and above the second sleeve collar (144). [8] The wellbore fluid communication tool (46) of claim 1, wherein the outer sleeve assembly (108) further comprises a plurality of lugs (154) operable to selectively engage the plurality of grooves (194) and the lower mandrel shoulder (196) of the inner mandrel (114). [9] The wellbore fluid communication tool (46) of claim 1, further comprising a second seat assembly (208) disposed within the inner mandrel (114) proximate the lower mandrel shoulder (196). [10] A wellbore fluid communication tool (46), the wellbore fluid communication tool (46) comprising: a housing (100) having a central passage (102) extending between a first end and a second end and defined along a longitudinal axis (104), the housing (100) having at least one radial port (130); a seal assembly (106) disposed along the housing (100) along the central passage (102), the seal assembly (106) including a first housing opening seal (132) between the radial port (130) and the first end of the housing; an outer sleeve assembly (108) disposed radially inwardly of the housing (100) along the central passage (102), the outer sleeve assembly (108) having a first door (146) and a second door (148) adjacent to each other to define a door gap (150) in a closed configuration, wherein the door gap (150) is positioned between the seal assembly (106) and the first end of the housing (100) when the first door (146) and the second door (148) are in the first closed configuration; an inner mandrel (114) having a radial opening (190), the inner mandrel (114) being disposed radially inward of the outer sleeve assembly (108) such that the radial opening (190) is adjacent the door gap (150), the inner mandrel (114) having a plurality of grooves (194) defined therein; a first releasable locking mechanism securing the outer sleeve assembly (108) to the housing (100) in the first locked position; a first releasable fastening mechanism (154) extending from the outer sleeve assembly (108) to engage a groove of the inner mandrel (114) to secure the inner mandrel (114) to the outer sleeve assembly (108) in the first position; and a first seat assembly (198) disposed within the outer sleeve assembly (108) and coupled to the inner mandrel (114) for axially moving with the outer sleeve assembly (108) and the inner mandrel (114) when a first object (204) is deposited within the first seat assembly (198); wherein the outer sleeve assembly (108) and the inner mandrel (114) are axially displaceable within the housing (100) with the door gap (150) in the first closed configuration to a second position when the first releasable locking mechanism is released; and wherein the first releasable fastening mechanism (154) is operable to release the groove of the inner mandrel (114) with the outer sleeve assembly (108) in the second position to separate the first door (146) and second door (148) to define an open configuration of the door gap (150). [11] The downhole fluid communication tool (46) of claim 10, wherein the outer sleeve assembly (108) includes a shoulder (170) and the downhole fluid communication tool (46) further comprises an intermediate housing ring (110) secured to the housing (100) by a second releasable locking mechanism, the intermediate housing ring (110) being spaced from the shoulder (170) when the downhole fluid communication tool (46) is in the first position. [12] The downhole fluid communication tool (46) of claim 10, wherein the first releasable locking mechanism is a shear pin. [13] The downhole fluid communication tool (46) of claim 10, wherein a seal assembly (106) is disposed along the housing (100) on opposite sides of the radial port (130). [14] The wellbore fluid communication tool (46) of claim 10, wherein the outer sleeve assembly (108) further comprises a first sleeve collar (142) and a second sleeve collar (144) positioned below the first door (146) and the second door (148). [15] A method of performing cementing operations in a wellbore (20), the method comprising: Positioning a cementing tool in a wellbore (20) at a first location spaced from a second location located downstream of the first location; Carrying out cementing operations at the second location; after the cementing operations at the second location, applying a first pressure to the cementing tool to jointly displace a substantially abutting first door (146) and second door (148) over a seal of the cementing tool such that a door gap (150) defined between the first door (146) and the second door (148) is translated into a closed configuration; Applying a second pressure to the cementing tool to (i) align an opening in an interior of the cementing tool, which is located radially inward of the first door (146) and the second door (148), with a port of the cementing tool and (ii) after jointly displacing the first door (146) and the second door (148), individually displace the opening away from the first door (146), thereby establishing fluid communication between the opening and the port; and Performing cementing operations at the second location through the opening between the first door (146) and second door (148) and through the connection of the cementing tool. [16] The method of claim 15, wherein cementing operations at the second location include directing cementing fluid through the aligned opening and the aligned port to deliver cementing fluid to an annulus around the cementing tool. [17] The method of claim 15, wherein the first pressure is applied by placing an object (204) on a seat within the cementing tool and applying pressure to the object (204) until a shear mechanism bursts, thereby allowing the first door (246) and the second door (248) to slide together. [18] The method of claim 15, wherein performing cementing operations at the second location comprises driving the deployed object (204) from a seat and directing cementing fluids through the seat to the aligned opening and port. [19] A method for establishing fluid communication in a wellbore (20), comprising: Positioning a downhole fluid communication tool (46) in a wellbore (20), the downhole fluid communication tool (46) comprising a tubular housing (100) having a radial opening defined therein, an inner mandrel (114) disposed radially within the housing (100) and defining a radial opening therein, and a sleeve (108) having a first door (146) and a second door (148) disposed radially between the tubular housing (100) and the inner mandrel (114); Applying a first pressure to the downhole fluid communication tool (46) to jointly displace the first door (146) and the second door (148) of the downhole fluid communication tool (46) such that a door gap (150) defined between the first door (146) and the second door (148) is displaced in a closed configuration over a seal; and Applying a second pressure to the downhole fluid communication tool (46) to (i) align the opening of the downhole fluid communication tool (46) with an internal port of the downhole fluid communication tool (46) and (ii) move the second door (148) away from the first door (146), thereby establishing fluid communication between the opening and the port through the door gap (150) in an open configuration. [20] The method of claim 19, wherein the first pressure is applied by placing an object (204) in a seat of the tool and applying the first pressure to the object (204) until a shear pin releases the first door (146) and the second door (148) from a first closed position, whereby the doors (146; 148) move together to a second closed position.

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