CHAMBER CLOSURE CONNECTION FOR DRILL RISER AUXILIARY LINE

Abstract

A drill string system for a riser includes a first part of the riser configured to connect to a first section of the riser, a second part of the riser configured to connect to a second section of the riser, and a chamber closure connection. The chamber closure connection includes a first part configured to connect to the first part of the riser and comprising a first coupling element, and a second part configured to connect to the second part of the riser and comprising a second coupling element. The chamber closure connection is configured to adjust between a locked and an unlocked configuration.

Description

CHAMBER CLOSURE CONNECTION FOR DRILLING RISER AUXILIARY LINE Cross-reference with related applications This document is based upon and claims priority from U.S. non-provisional patent application serial number 16 / 939940, filed on July 27, 2020, which is incorporated herein by reference in its entirety. Background of the invention This section is intended to introduce the reader to various aspects of the technique that may be related to several aspects of the present description that are described and / or claimed later. It is believed that this analysis is useful in providing the reader with background information to facilitate a better understanding of the various aspects of the present description. Accordingly, these statements should be understood as such and not as admissions of prior art. Natural resources have a profound impact on modern economies and societies. To meet the demand for these resources, many companies invest significant amounts of time and money in the exploration, access, and extraction of oil, natural gas, and other natural resources. In particular, once a desired natural resource is discovered beneath the Earth's surface, drilling systems are often employed to access it. These drilling systems may be located onshore or offshore, depending on the resource's location. Such drilling systems may include a drilling fluid system configured to circulate drilling fluid in and out of a borehole to facilitate drilling. Brief description of the figures Several features, aspects, and advantages of the present description will be better understood when the following detailed description is read with reference to the accompanying figures, in which similar characters represent similar parts in all figures where: Figure 1 is a schematic diagram of a drilling system, according to one modality of this disclosure; Figure 2 is a perspective view of an integrated riser joint (IRJ) that can be used in the drilling system of Figure 1, according to one embodiment of the present description; Figure 3 is a cross-sectional side view of the IRJ of Figure 2, according to one modality of the present disclosure; Figure 4 is a cross-sectional side view of a portion of the IRJ of Figure 2, according to one modality of the present disclosure; ML / E / ZuZo / u ÓOOÍ Figure 5 is a perspective view of a portion of the IRJ of Figure 2, according to a modality of the present disclosure; Figure 6 is a perspective view of a portion of the IRJ taken within line 6-6 of Figure 5, wherein said portion includes a chamber closure connection, according to a modality of the present description; Figure 7 is an exploded view of the chamber closure connection of Figure 6, according to one embodiment of the present description; and Figure 8 is a cross-sectional side view of the chamber closure connection of Figure 6, according to one embodiment of the present disclosure. Detailed description of specific modalities The following describes one or more specific modalities of this disclosure. These described modalities are merely examples within this disclosure. Furthermore, in an effort to provide a concise description of these example modalities, not all features of an actual implementation may be described in the disclosure. It should be noted that in developing any actual implementation, for example, in any engineering or design project, many implementation-specific decisions must be made to achieve the developers' specific objectives, such as meeting system-related and activity-related constraints, which may vary from one implementation to another.It will also be appreciated that such a development effort could be complex and time-consuming, but it would nevertheless be a routine task of design, manufacture, and elaboration for those skilled in the art who have access to this description. When elements of various forms are presented, the terms "a," "an," "the," "said," and the like are intended to signify that there is one or more of the elements. The terms "comprising," "including," "having," and the like are intended to be inclusive and to refer to the possibility of additional elements beyond those listed. The use of "above," "below," "over," "below," and variations of these expressions is for convenience but does not imply any particular orientation of the components relative to any fixed reference point, such as the direction of gravity. The term "fluid" encompasses liquids, gases, vapors, and combinations thereof. Numerical terms, such as "first," "second," and "third," may be used to distinguish components for the sake of ease of analysis, and it should be noted that numerical terms may be used differently or assigned to different elements in the claims.The figures are not necessarily to scale. Certain features and components in this document may be shown in exaggerated scale and / or somewhat schematically. Some details may be omitted for the sake of clarity and conciseness. As previously stated, a drilling system may include a drilling fluid system configured to circulate drilling fluid into and out of a ML / E / ZuZo / u ÓOOZ hole in order to facilitate drilling the hole. For example, the drilling fluid system can provide a flow of drilling fluid through a drill string when the drill string rotates a drill bit that is located in a portion of the distal end of the drill string. The drilling fluid can exit through one or more openings in the distal end portion of the drill string and can return to a drilling system rig through an annular space between the drill string and a casing pipe lining the hole. In some cases, the drilling system may employ pressure management during drilling (PMD). PMD regulates the pressure and flow rate of the drilling fluid within the drill string so that the fluid flow rate does not over-pressurize a well (e.g., expand the well) and / or prevent the well from collapsing under its own weight. The ability to control the pressure and flow rate of the drilling fluid allows the drilling system to be used to drill in various locations, such as areas with relatively softer seabeds. The drilling system described in this disclosure may include an integrated riser joint (IRJ), which may include a rotating control device (RCD), an annular blowout preventer (BOP), and / or other components (e.g., a flow coil). The IRJ may include a housing (e.g., a multi-section housing) that defines an orifice, and the drill string may be extended through the orifice during drilling operations. The RCD may include an RCD closure element configured to seal and rotate with the drill string to block the passage of a fluid flow (e.g., drilling fluid, drill cuttings, and / or natural resources [e.g., carbon dioxide, hydrogen sulfide]) through the RCD closure element from the wellbore to the rig.Similarly, the annular BOP may include an annular BOP shut-off element configured to seal against the drill string and / or itself (e.g., through the orifice) to block fluid flow through the annular BOP shut-off element from the well to the platform. While the RCD shut-off element and / or the annular BOP shut-off element are in a closed configuration, fluid flow can be diverted to another suitable location (e.g., a collection tank) other than the platform. As discussed in more detail below, the IRJ may include one or more auxiliary lines that are positioned outside the IRJ housing and extend along the length of the IRJ. Advantageously, for each auxiliary line, a breech-lock connection can be used to couple sections of the auxiliary line together. The breech-lock connection can facilitate maintenance operations (e.g., inspection, repair, replacement) for the IRJ. For example, if the IRJ is raised onto a surface and supported by a spider, the breech-lock connection can be adjusted from a locked configuration, where the connection couples the auxiliary line sections together, to a closed configuration. ML / E / ZuZo / uO ÓOOZ unlocked in which the breech-lock connection does not couple the auxiliary line sections together. Then, while the breech-lock connection is in the unlocked configuration and the auxiliary line sections are not coupled together, the IRJ housing sections can also be separated from each other to allow an operator access to the RCD locking element, the annular BOP locking element, and / or other components within the IRJ. Bearing in mind the foregoing, Figure 1 is a schematic diagram of one embodiment of a drilling system 10 configured for drilling operations. The drilling system 10 may be a subsea system, although the embodiments described can be adapted for use in a land-based (e.g., surface) system. The drilling system 10 may utilize MPD techniques. As illustrated, the drilling system 10 includes a wellhead 12 coupled to a mineral deposit via a shaft 16 having a borehole 18. Wellhead 12 may include or be connected to multiple components that control and regulate the activities and conditions associated with well 16. For example, wellhead 12 typically includes or is connected to pipes, bodies, valves, and seals that enable drilling well 16, directing the minerals produced from the ore deposit, regulating the pressure in well 16, and providing the injection of drilling fluids into hole 18. A conductor may provide structure for hole 18 and prevent the collapse of the sides of well 16 into hole 18. Casing may be run inside the conductor. The casing may provide structure for hole 18 and facilitate fluid and pressure control during the drilling of well 16. A drill riser 20 may extend between the wellhead 12 and a platform 22. The platform 22 may include or support various components that facilitate the operation of the drilling system 10, such as pumps, tanks, and power systems. The platform 22 may also include a derrick 24 that supports a tubular 26 (e.g., a drill string), which may extend through the drill riser 20. A drilling fluid system 28 may direct drilling fluid into the tubular 26, and the drilling fluid may exit through one or more openings in a portion of the distal end 30 of the tubular 26 and return (along with drill cuttings and / or other substances from well 16) to the platform 22 through an annular space (e.g., between the tubular 26 and the casing lining the hole 18; between the tubular 26 and the drill riser 20).A drill bit 32 can be placed in the distal end portion 30 of the tubular 26. The tubular 26 can be rotated within the riser drill pipe 20 to rotate the drill bit 32, allowing the drill bit 32 to drill and form the well 16. As shown, the drilling system 10 may include an integrated riser joint (IRJ) 40 that is part of the drilling riser 20. The drilling system 10 may also include other features, such as a telescopic riser joint (TRJ, IVIA / t / ZUZÓ / UI ÓOO / (in English) 42, which is configured to allow the lifting of platform 22 and standard riser joints 44 (e.g., bare riser joints, hollow pipes). TRJ 42 and standard riser joints 44 can also be part of the drill riser 20. As shown, IRJ 40 is positioned between TRJ 42 and standard riser joints 44. The IRJ 40 may include a rotary control device (RCD), an annular blowout preventer (BOP), and / or other components (e.g., a flow coil). The IRJ 40 may also include one or more auxiliary lines 46, which can supply fluid (e.g., high-pressure fluid from a fluid source 48) to wellhead components 12 and / or support control and / or power lines for wellhead components 12, for example. As discussed in more detail below, a chamber shut-in connection 50 (e.g., a chamber shut-in system) may be provided for each auxiliary line 46. Together, the chamber shut-in connection 50 and the auxiliary line 46 can form an auxiliary line system. The chamber shut-in connection 50 can facilitate maintenance operations of the IRJ 40.Drilling system 10 and its components can be described with reference to the vertical axis 2 (or vertical direction), a radial axis 4 (or longitudinal direction), and a circumferential axis 6 (or direction) for ease of analysis. Figure 2 is a perspective view of the IRJ 40, which can be used in the drilling system of Figure 1. As shown, the IRJ 40 includes a housing 60 (e.g., a multi-section housing) extending from a first end 62 to a second end 64. The first end 62 can be configured to engage with a first part of the drill riser, such as the TRJ, and the second end 64 can be configured to engage with a second part of the drill riser, such as one of the standard riser couplings. In this way, a hole 66 of the IRJ 40 can be aligned (e.g., along the vertical axis 2) and / or seamlessly engaged with holes in other parts of the drill riser to form a continuous hole that extends through the entire drill riser. Housing 60 may have multiple sections that are coupled together by one or more fasteners (e.g., threaded fasteners such as bolts). In the illustrated embodiment, housing 60 includes a first section 70 (e.g., RCD section) that houses an RCD, a second section 72 (e.g., annular BOP section) that houses an annular BOP, and a third section 74 (e.g., flow coil section) that may house another component, such as a flow coil that facilitates the return of drilling fluid (along with drill cuttings and / or natural resources) to the rig. The IRJ 40 also includes one or more auxiliary lines 46, which can supply fluid to wellhead components and / or support control and / or power lines for wellhead components, for example. As shown, the multiple auxiliary lines 46 can be separated and distributed circumferentially around the housing 60, and each ML / E / ZuZo / uO ÓOOÍ auxiliary line 46 can be extended from the first end 62 to the second end 64 of the IRJ 40. A respective chamber closure connection 50 is provided for each auxiliary line 46. Figure 3 is a cross-sectional side view of the IRJ 40 shown in Figure 2. As shown, the IRJ 40 includes the housing 60, which extends from the first end 62 to the second end 64. The housing 60 defines the bore 66 and includes multiple sections 70, 72, and 74 that are coupled together by one or more fasteners. Specifically, the first section 70 houses an RCD 80, the second section 72 houses an annular BOP 82, and the third section 74 can house another component, such as a flux coil. RCD 80 may include an RCD 84 closure element (e.g., one or more annular closure elements) configured to seal and rotate with the drill string to block fluid flow through the RCD 84 closure element of RCD 80 from the wellbore to the rig. Similarly, annular BOP 82 may include an annular BOP 86 closure element configured to seal against the drill string and / or itself (e.g., through hole 66) to block fluid flow through the annular BOP 86 closure element of annular BOP 82 from the wellbore to the rig. While the RCD 84 closure element and / or the annular BOP 86 closure element are in a closed configuration (e.g., to seal hole 66), fluid flow may be diverted to another suitable location (e.g., a collection tank) other than the rig. As shown, the IRJ 40 also includes one or more auxiliary lines 46. The auxiliary lines 46 are positioned outside (e.g., radially outward) the housing 60, and each auxiliary line 46 extends from the first end 62 to the second end 64 of the IRJ 40. A respective chamber closure connection 50 is also provided for each auxiliary line 46. Additional structural and operational features of the chamber closure connection 50 can be understood with reference to Figures 4-8. Figure 4 is a cross-sectional side view of a portion of IRJ 40 from Figure 3. As shown, IRJ 40 includes the housing 60 that defines the bore 66 and includes multiple sections 70, 72 that are coupled together by one or more fasteners 90. In the illustrated embodiment, the first section 70 houses the RCD 80 and the second section 72 houses the annular BOP 82. In addition, the second section 72 includes a first annular BOP part 92 and a second annular BOP part 94 that together support and surround the annular BOP closing element 86. The first annular BOP part 92 and the second annular BOP part 94 can also be coupled by their respective fasteners 90. However, other configurations of the first section 70 and / or the second section 72 are provided for. The one or more auxiliary lines 46 are located on the exterior of the housing 60. Each auxiliary line 46 also includes a first part of auxiliary line 100 and a second part of auxiliary line 102, which are configured to couple to each other via the respective breech closure connection 50. As shown, each breech closure connection 50 includes a ML / E / ZuZo / uO ÓOOZ rod part 104 (e.g., male connector; floating male tip; second part) and a receptacle part 106 (e.g., female connector; first part; ring part). In some embodiments, the receptacle part 106 may include multiple components, such as a housing 108 (e.g., an annular housing) and a hub 110 (e.g., an annular hub, a locking hub). However, other configurations of the receptacle part 106 are contemplated. For example, the housing 108 and the hub 110 may be integrally formed as a single piece. Alternatively, the housing 108 may be integrally formed with the first part of the auxiliary line 100. As discussed in more detail below, the rod portion 104 may include a respective coupling element (e.g., a second coupling element), such as rod protrusions extending radially outward (e.g., one or more protrusions) that are circumferentially spaced from each other around the rod portion 104. In addition, the receptacle portion 106 may include respective coupling elements (e.g., first coupling elements), such as receptacle protrusions extending radially inward (e.g., one or more protrusions) that are circumferentially spaced from each other around the receptacle portion 106.In such cases, the rod protrusions and the receptacle protrusions can be spaced to allow the rod portion 104 to be received within the receptacle portion 106 (e.g., such that the receptacle portion 106 circumferentially surrounds the rod portion 104), and then by rotating at least one of the components (e.g., by rotating at least part of the receptacle portion 106), the rod protrusions and the receptacle protrusions can engage with each other (e.g., overlap) to retain the rod portion 104 within the receptacle portion 106 (e.g., to block movement of the rod portion 104 along the vertical axis 2, such as movement of the rod portion 104 downward along the vertical axis 2 into the well when installed as part of the riser for the well).As shown, the second part of the auxiliary line 102 includes a fitting 112 that is configured to receive and circumferentially surround at least part of the rod portion 104. In the illustrated embodiment of Figure 4, each of the chamber closure connections 50 is in a locked configuration (e.g., a mated configuration) in which the rod protrusions and the receptacle protrusions are mated together to retain the rod portion 104 within the receptacle portion 106. In the locked configuration, the chamber closure connection 50 couples the first part of the auxiliary line 100 to the second part of the auxiliary line 102 to form a continuous auxiliary line 46 (e.g., continuous from the first end to the second end of IRJ 40) that is configured to support a flow of fluid or cables (e.g., power cables), for example. Each of the breech-lock connections 50 can be adjusted from the locked configuration to an unlocked configuration (e.g., disengaged configuration) in which the rod protrusions and the receptacle protrusions do not engage with each other. In particular, to move to the unlocked configuration, at least one part of the breech-lock connection 50, such as at least part of the receptacle portion 106, can be rotated to disengage the rod protrusions and the receptacle protrusions from each other. This rotation allows the rod portion 104 to then move along the vertical axis 2 (e.g., downwards along the vertical axis 2) along the second part of the auxiliary line 102 and / or within the recess 112. The rod portion 104 can move in this manner due to gravitational force and / or another applied force (e.g., by the operator).In the unlocked configuration, the breech-lock connection 50 does not couple the first part of the auxiliary line 100 to the second part of the auxiliary line 102, and therefore the first part of the auxiliary line 100 and the second part of the auxiliary line 102 are physically separated from each other (e.g., disconnected, interrupted) and do not form the continuous auxiliary line 46. It may be convenient to adjust the breech-lock connection 50 to the unlocked configuration to cause the separation of the first part of the auxiliary line 100 and the second part of the auxiliary line 102 during certain maintenance operations. For example, to complete certain maintenance operations (e.g., inspecting, repairing, or replacing the annular BOP 86 locking element), a lifting device may raise the IRJ 40 onto a spider on the platform. An operator (or device) may then rotate at least one of the components of the breech-lock connection 50 as described herein to cause the rod protrusions and the receptacle protrusions to disengage from each other. As a result, the rod portion 104 may slide or move along the vertical axis 2 into the recess 112.One or more fasteners 90 can then be adjusted to allow the first section 70 and the second section 72 of the housing 60 to separate from each other. For example, the first section 70 of the housing 60 can be lifted off the second section 72 of the housing 60, while the second section 12 of the housing 60 remains supported on the spider. In some embodiments, the second section 72 of the housing 60 can remain supported on the spider in a generally vertical position (e.g., a central axis of the second section 72 of the housing 60 is aligned with the vertical axis 2; the second section 72 is not positioned on its side). In this way, the operator can complete maintenance operations on the first section 70 of housing 60 (and the components supported or attached to it, such as the RCD closure element) and the second section 72 of housing 60 (and the components supported or attached to it, such as the annular BOP closure element 86) without disconnecting the auxiliary lines 46 from housing 60. In particular, the first part of auxiliary line 100 can remain attached to the first section 70 of housing 60 (for example, to a respective flange of the first section 70 of housing 60), and the second part of auxiliary line 102 can remain attached to the second section 72 of housing 60 (for example, to a respective flange of the second section 72 of housing 60) during maintenance operations.Furthermore, the receptacle portion 106 of the chamber closure connection 50 can remain attached to the first section 70 of the housing 60 (e.g., through the first part of the. MLE / E / ZuZo / uJ 300 / auxiliary line 100), and / or the rod portion 104 of the chamber closure connection 50 can remain attached to the second section 72 of the housing 60 (e.g., via the second portion of the auxiliary line 102; supported within the recess 112) during maintenance operations. Advantageously, the operator does not have to lift or remove the entire length of the auxiliary line 46 separately (e.g., extending from the first end to the second end of the IRJ 40) or detach the auxiliary line 46 from the housing 60 to access components of the IRJ 40, such as the closing element of the annular BOP 86. Thus, maintenance operations can be carried out efficiently, resulting, for example, in cost savings. Figure 5 is a perspective view of a portion of IRJ 40. As shown, IRJ 40 includes housing 60, which defines the bore, and multiple sections 70 and 72 that are mated together by one or more fasteners 90. In the illustrated embodiment, the first section 70 houses the RCD 80, and the second section 72 houses the annular BOP 82. One or more auxiliary lines 46 are located outside housing 60. Each auxiliary line 46 also includes the first part of auxiliary line 100 and the second part of auxiliary line 102, which are configured to be mated together by the respective chamber closure connection 50. As shown, each chamber closure connection 50 includes the rod portion 104 and the receptacle portion 106. In some embodiments, the receptacle portion 106 may include the box 108 and the hub. 110.In Figure 6, which is a perspective view of a portion of the IRJ 40 taken within line 6-6 of Figure 5, additional features of the breech closure connection 50 are shown. Figure 7 is an exploded view of a portion of the breech-lock connection 50. As shown, the breech-lock connection 50 includes the rod portion 104 and the receptacle portion 106. In some embodiments, the receptacle portion 106 may include the box 108 and the hub 110. As shown, the rod portion 104 includes protrusions of the rod 120 (e.g., extending radially outward; second protrusions) that are circumferentially spaced around the rod portion 104 (e.g., around a respective side wall of the rod portion 104). In addition, receptacle portion 106 includes receptacle protrusions 122 (e.g., extending radially inward; first protrusions) that are circumferentially spaced from each other around receptacle portion 106 (e.g., around a respective side wall of receptacle portion 106).The protrusions of rod 120 and the protrusions of receptacle 122 are separated to allow the portion of rod 104 to be received within the portion of receptacle 106 (for example, while the portion of rod 104 and the portion of receptacle 106 are in a first configuration relative to each other; while the protrusions of rod 120 are misaligned with the protrusions of receptacle 122). For example, the protrusions of rod 120 can fit between the protrusions of receptacle 122 as the portion of rod 104 moves into the portion of receptacle 106 along the vertical axis 2. Once the protrusions of rod 120 pass through the protrusions of receptacle 122, at least one of the components (e.g., at least the hub 110) can be rotated out. ML / E / ZuZo / uO ÓOOÍ so that the protrusions of rod 120 and the protrusions of receptacle 122 overlap (e.g., are stacked along the vertical axis 2) and engage with each other to retain the rod portion 104 within the receptacle portion 106 (e.g., to block movement of the rod portion 104 along the vertical axis 2, such as movement of the rod portion 104 downward along the vertical axis 2 into the hole when installed as part of the well drilling riser). When receptacle portion 106 includes housing 108 and hub 110, housing 108 and hub 110 can be coupled to each other via a threaded interface. For example, housing 108 can include threads on a radially outside surface of housing 108, and hub 110 can include threads on a radially inside surface of hub 110. The threads on housing 126 and the threads on hub 128 can be configured to mesh together. With this configuration, housing 108 can be coupled (for example, non-rotatingly coupled) to the first part of the auxiliary line. Therefore, the 108 housing and the first part of the auxiliary line can generally remain in place with respect to the IRJ housing, and the 110 hub can be rotated (e.g., by the operator) with respect to the 108 housing via the threaded interface.The rod part 104 can rest on the second part of the auxiliary line (for example, sliding into the recess of the second part of the auxiliary line). The 50 breech-lock connection may include several features to facilitate adjustment between the unlocked and locked configurations. For example, as shown, the 110 cube may include a 130 cube indicator (e.g., a visual indicator, such as a symbol), and the 108 box may include a 132 box indicator (e.g., a visual indicator, such as text). When the 130 indicator on the 110 cube and the 132 indicator on the box are aligned (e.g., the symbol is aligned with the text that says "unlocked"), this can indicate to the operator that the 50 breech-lock connection is in the unlocked configuration. In some embodiments, the hub 110 may include a tool recess 134 configured to receive and be engaged by a tool (e.g., operated by the operator). In some embodiments, the tool may be used to facilitate rotation of the hub 110 and / or to lock the hub 110 to the rod portion 104 to maintain the locked configuration. For example, in the locked configuration, the tool recess 134 may be a recess 138 on the rod portion 104. Then, after insertion of the tool (e.g., the locking rod or threaded fastener) into the tool recess 134 and the recess 138 into the rod portion 104, the tool can block relative movement between the hub 110 and the rod portion 104. It should be noted that the tool recess 134 and the recess 138 may be provided in any suitable location.In addition, the breech-locking connection 50 may include separate inserts for coupling with the hub-turning tool 110 and for coupling with the hub-locking tool 110. As shown, the rod portion 104 and / or the hub 110 (e.g., the receptacle protrusions 122) may include. ML / E / ZuZo / u ÓOOÍ several conical surfaces 136 to facilitate the centering and / or sliding of the rod part 104 within the cube 110. In some embodiments, one or more stops (e.g., protrusions) and / or corresponding notches (e.g., grooves) may be provided to block (e.g., limit) the rotation of the hub 110 and / or provide a tactile indication of whether the breechblock configuration 50 is in the locked or unlocked configuration. As shown, the rod portion 104 may include a flange 143 (e.g., a radially extending flange) that is configured to engage with a side wall (e.g., an annular wall) of the second auxiliary line portion to block the travel of the rod portion 104 toward the locking mechanism (e.g., so that at least a portion of the rod portion 104 remains exposed in the unlocked configuration).Although the description provides examples of rotation of the 110 hub, it should be appreciated that either the 110 hub or the 104 rod portion, or both, can be rotated to adjust the 50 breech lock connection between the locked and unlocked configurations. Figure 8 is a cross-sectional side view of the breech-lock connection components 50 within the IRJ 40. As shown, the IRJ 40 includes the housing 60, and one or more auxiliary lines 46 are located outside the housing 60. Each auxiliary line 46 includes the first part of auxiliary line 100 and the second part of auxiliary line 102, which are configured to couple with each other via the respective breech-lock connection 50. As shown, each breech-lock connection 50 includes the rod portion 104 and the receptacle portion 106, which may include the box 108 and the hub 110. In the locked configuration, the rod protrusions 120 and the receptacle protrusions 122 couple with each other (e.g., they are stacked along the vertical axis 2).In some embodiments, in the locked configuration, the protrusions of rod 120 may be positioned between the protrusions of receptacle 122 and a surface 140 of housing 108 and / or may be in contact with them (e.g., trapped between them). Furthermore, the surface 140 may include circumferentially spaced recesses 142 (e.g., grooves) that can receive the protrusions of rod 120 and / or retain the protrusions of rod 120 in the locked configuration (e.g., blocking movement along the vertical axis 2 and / or the circumferential axis 6). As shown, the rod portion 104 may also include the flange 143. In addition, to seal the auxiliary line 46 (e.g., to provide a fluid-tight passage or conduit), one or more sealing elements 144 (e.g., annular sealing elements) may be provided.For example, one or more sealing elements 144 may be provided to seal between the rod portion 104 and the receptacle portion 106, and one or more sealing elements 144 may be provided to seal between the rod portion 104 and the second auxiliary line portion 102. The breech-lock connection 50 is located (e.g., along the vertical axis 2) so that the fasteners coupling the housing sections 60 together are exposed or accessible while the breech-lock connection 50 is in the unlocked configuration (e.g., the rod portion 104 is sliding). ML / E / ZuZo / u ÓOOÍ into the 112 slot to expose the fasteners). It should be noted that all the features discussed above with respect to Figures 1-8 can be combined in any suitable manner. Furthermore, several modifications are provided for. For example, while the rod portion 104 is shown as being received within the receptacle portion 106, it should be noted that the rod portion 104 can be hollow and the receptacle portion 106 can be received within the rod portion 104 (e.g., the protrusions of rod 120 can extend radially inward and the protrusions of the receptacle can extend radially outward). As another example, the rod portion 104 can be coupled to the first part of the auxiliary line 100, while the receptacle portion 106 can be coupled to the second part of the auxiliary line 102 (e.g., the rod portion 104 is positioned vertically on top of the receptacle portion 106).As another example, the second part of auxiliary line 102 can be received within a recess of rod portion 104 (e.g., rod portion 104 can circumferentially encircle the second part of auxiliary line 102). The chamber closure connection can also be adapted for use with auxiliary lines in other parts of the drill riser, in other drill riser configurations (e.g., without the IRJ), or in any other part of the drilling system. While the description may be subject to various modifications and alternative forms, specific modalities have been shown by way of example in the figures and are described in more detail herein. However, it should be understood that the disclosure is not intended to be limited to the specific forms described. Instead, the disclosure is intended to cover all modifications, equivalences, and alternatives encompassed within the spirit and scope of the disclosure as defined in the following appended claims.

Claims

1. An auxiliary line system for a drill riser, wherein the auxiliary line system comprises: a first auxiliary line portion configured to couple to a first section of the drill riser; a second auxiliary line portion configured to couple to a second section of the drill riser; and a chamber closure connection, comprising: a first portion configured to couple to the first auxiliary line portion and comprising a first coupling element;and a second part configured to couple to the second part of the auxiliary line and comprising a second coupling element, wherein the breech-locking connection is configured to fit between a locked configuration in which the first coupling element and the second coupling element are coupled to each other to block relative movement between the first part and the second part and an unlocked configuration in which the first coupling element and the second coupling element are uncoupled from each other to allow relative movement between the first part and the second part.

2. The auxiliary line system of claim 1, wherein the first part of the auxiliary line, the second part of the auxiliary line and the breech-lock connection are configured to form a continuous auxiliary line while the breech-lock connection is in the locked configuration.

3. The auxiliary line system of claim 1, wherein the first part comprises a rod portion and the second part comprises a receptacle portion configured to receive the rod portion.

4. The auxiliary line system of claim 1, wherein the first coupling element comprises first radially extending protrusions, and the second coupling elements comprise second radially extending protrusions.

5. The auxiliary line system of claim 4, wherein the first radially extending protrusions are circumferentially spaced around the first part, and the second radially extending protrusions are circumferentially spaced around the second part.

6. The auxiliary line system of claim 5, wherein the first radially extending protrusions and the second radially extending protrusions are separated to allow each of the second radially extending protrusions to pass between the adjacent first radially extending protrusions.

7. The auxiliary line system of claim 1, wherein the first part comprises an annular hub comprising the first coupling element, and the annular hub is configured to rotate with respect to the second part to adjust the breech-locking connection between the locked and unlocked configurations.

8. The auxiliary line system of claim 7, wherein the first part comprises an annular housing that is non-rotatingly coupled to the first part of the auxiliary line and that is threaded to the annular hub.

9. The auxiliary line system of claim 1, comprising a first recess in the first part and a second recess in the second part, wherein the first recess and the second recess are configured to align with each other while the breech-locking connection is in the locked configuration to allow the insertion of a locking tool into the first recess and the second recess.

10. A drill riser joint for a drilling system, wherein the drill riser joint comprises: a housing comprising a first section and a second section configured to couple to each other via one or more threaded fasteners; a first auxiliary line portion configured to couple to the first section of the housing; a second auxiliary line portion configured to couple to the second section of the housing; and a chamber closure connection, comprising: a receptacle portion configured to couple to the first auxiliary line portion and comprising radially extending receptacle protrusions;and a rod portion configured to engage with the second part of the auxiliary line and comprising radially extending rod protrusions configured to engage radially extending receptacle protrusions in a locked configuration in which vertical movement of the rod portion relative to the receptacle portion is locked.

11. The riser drilling joint of claim 10, comprising a rotary control device located within the housing.

12. The riser drilling joint of claim 11, comprising an annular blowout preventer positioned within the second housing section, wherein the rotary control device is positioned within the first housing section.

13. The riser drill pipe joint of claim 10, wherein the second part of the auxiliary line comprises a fitting, and the rod portion is configured to slide into the fitting so as to slide-couple to the second part of the auxiliary line.

14. The riser drill pipe joint of claim 10, wherein the radially extending receptacle protrusions are circumferentially spaced ML / E / ZuZo / u / ZoO ÓOOZ around the receptacle portion, and the radially extending rod protrusions are circumferentially spaced around the rod portion.

15. The drill riser joint of claim 10, wherein the first part of the auxiliary line, the second part of the auxiliary line, and the chamber closure connection are configured to form a continuous auxiliary line extending from a first end of the drill riser joint to a second end of the drill riser joint while the chamber closure connection is in the locked configuration.

16. The riser drill pipe joint of claim 15, wherein the first part of the auxiliary line, the second part of the auxiliary line, and the chamber closure connection are configured not to form the continuous auxiliary line while the chamber closure connection is in an unlocked configuration.

17. A method for performing a maintenance operation on a drill riser joint, wherein the method comprises: supporting the drill riser joint on a platform; adjusting a chamber closure connection of an auxiliary line system from a locked configuration to an unlocked configuration to separate a first part of the auxiliary line coupled to a first section of a drill riser joint housing from a second part of the auxiliary line coupled to a second section of the drill riser joint housing from each other; and adjusting one or more threaded fasteners to separate the first section of the housing and the second section of the housing from each other to access the components within the housing.

18. The method of claim 17, comprising separating the first housing section and the second housing section from each other without decoupling the first part of the auxiliary line from the first housing section and without decoupling the second part of the auxiliary line from the second housing section.

19. The method of claim 17, wherein adjusting the breech-lock connection of the auxiliary line system comprises rotating at least a portion of a breech-lock connection receptacle portion with respect to a rod portion of the breech-lock connection to thereby decouple the receptacle portion from the rod portion.

20. The method of claim 19, wherein adjusting the breech-lock connection of the auxiliary line system comprises uncoupling the receptacle protrusions from the rod protrusions by rotating at least the receptacle portion of the breech-lock connection.

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