Dual-activity riser joint and methods

Abstract

A transition riser joint has a hollow body with a main branch and a main inlet connecting to a main outlet. The transition riser joint has an access branch with an access inlet connecting to the main outlet. A middle riser joint is connected to the access inlet and to an upper riser joint, which includes a pipe segment having proximal and distal end portions, with a lubricator or a rotating control device connected to the distal end portion. The lubricator has an interior and an inlet configured to permit an inserted device to pass from an open subsea location through the lubricator or a rotating control device, through the access branch, into the hollow body, and through the outlet, into the second pipe joint. The lubricator or a rotating control device sealingly engages an inserted device to seal an open subsea location from the interior of the hollow body.

Description

Docket No. 689764.2021 / 67WO1 (TOFF-067 / 01WO)FILED VIA EFSTITLE OF THE APPLICATIONDUAL-ACTIVITY RISER JOINT AND METHODSCROSS-REFERENCE TO RELATED APPLICATIONS

[0001] The present application is a continuation-in-part application of International Application No. PCT / US2024 / 044264 filed August 28, 2024, and claims the benefit of U.S. Provisional Patent Application No. 63 / 699,644, filed on September 26, 2024, each titled “Dual-Activity Riser Joint and Methods.” Each application cited in this paragraph is incorporated into the present application by reference.BACKGROUND OF THE DISCLOSURE

[0002] The present disclosure relates generally to the field of subsea drilling for hydrocarbons. More particularly, the present disclosure relates to subsea drilling devices, systems, and methods, by which drilling, wireline, or completions operations may be conducted using two distinct marine risers.

[0003] In subsea drilling for hydrocarbons, a well may be drilled in the sea floor using a sequence of drilling processes and may be the subject of wireline or completions operations. The drilling, wireline, or completions operations are commonly conducted from a drilling platform — for example, a drillship or other floating support body carrying at least one pipe-handling derrick. In subsea drilling, a wellhead assembly and a blowout preventer (also known as a “BOP” or “BOP stack”) are located on or near the sea floor. The BOP stack is latched to the wellhead assembly. A marine riser, which is a pipe serving as a conduit between the BOP stack and the drilling platform, is latched to the BOP stack. Thereafter, drilling, wireline, or completions operations may be performed through the marine riser, the BOP stack, and the wellhead assembly. The marine riser is serviced by a derrick on the drilling platform and may be accessed through a “moon pool” or{00359234;vl} 1Docket No. 689764.2021 / 67WO1 (TOFF-067 / 01 WO)FILED VIA EFS opening providing a passage from a deck of the drilling platform and providing access to the marine riser.

[0004] In certain systems, sometimes known as “dual-activity systems,” the drillship is configured and equipped for servicing two marine risers. U.S. Pat. No. 6,443,240 (“Scott”), the contents of which are incorporated herein, conducting devices and methods for conducing drilling, wireline, or completions operations through a first marine riser while assembling drill pipe, tools, or other equipment in the second marine riser. The use of two marine risers saves time as compared to use of a single marine riser. When a drilling, wireline, or completions operation (or a combination thereof) uses a single marine riser, the operation must be halted when drilling equipment used in the single marine riser requires modification or maintenance. In contrast, in a dual -activity system employing two marine risers, the equipment in the first marine riser can be modified or maintained in the first marine riser, while equipment in the second marine riser can be operated to continue the drilling, wireline, or completions operations.

[0005] The present disclosure relates to improved devices and methods for use in dual-activity systems.SUMMARY OF THE DISCLOSURE

[0006] Briefly stated, in a first embodiment, a system for subsea drilling includes: a Y-connector including a hollow body, the Y-connector having: a lower trunk having a lower passage in fluid communication with a main outlet; a first upper branch with a first inlet in fluid communication with a first outlet, the first upper branch being configured to operatively couple to a first marine riser, and the first outlet being in fluid communication with the lower passage of the lower trunk; and a second upper branch with a second inlet in fluid communication with a second outlet, the second upper branch being configured to operatively couple to a second marine riser, and the second outlet being in fluid communication with the lower passage of the lower trunk; and an articulating-rotating j oint configured to sealingly couple the lower trunk of the Y-connector to a blowout preventer.

[0007] The first embodiment may include any combination of optional features discussed in this paragraph. The system may further include one or more of the following: a first isolation valve disposed between the first inlet and the first outlet; a second isolation valve disposed between the second inlet and the second outlet; and a third isolation valve disposed between the lower trunk and the main outlet. The system may include the Y-connector being configured to sealingly couple aDocket No. 689764.2021 / 67WO1 (TOFF-067 / 01 WO)FILED VIA EFS selected one of the first upper branch or the second upper branch in fluid communication with the lower trunk. The articulating-rotating joint may comprise a ball joint. The articulating -rotating joint may include: a housing; and a ball body seated within the housing for articulation and rotation with respect to the housing, wherein the ball body is sealingly engaged with the housing so that the articulating-rotating joint provides a sealed connection joining the main outlet of the Y-connector to the blowout preventer. The system may further include a seal disposed between the housing and the ball body. The articulating-rotating joint may comprise one or more of a spherical roller bearing or packing-sealing elements. The articulating-rotating joint may comprise at least one rotary seal. The system may further include a closure body movable between: a first position opening a path between the first inlet and main outlet; and a second position opening a path between the second inlet and the main outlet. The first position of the closure body may close the path between the second inlet and main outlet; and the second position of the closure body closes a path between the first inlet and the main outlet. The system may further include a lubricator operatively coupled to lubricate the articulating-rotating joint or other components of the system. The system may further include a controller operatively coupled to at least one of the blowout preventer, the lubricator, the first isolation valve, the second isolation valve, or the third isolation valve.

[0008] In a second embodiment, the system may include: a first marine riser configured to be operatively coupled to a drilling platform, the first marine riser comprising a first upper-marine-riser segment and a first lower-marine-riser segment; a second marine riser configured to be operatively coupled to the drilling platform, the second marine riser comprising a second upper-marine-riser segment and a second lower-marine-riser segment; a first rotating-ball-joint-valve configured to operatively couple the first upper-marine-riser segment to the first lower-marine-riser segment; a second rotating-ball-joint-valve configured to operatively couple the second upper-marine-riser segment to the second lower-marine-riser segment; and a third rotating-ball-joint-valve operatively first marine riser and the second marine riser to a blowout preventer. The second embodiment may further comprise a swivel connector disposed between the third rotating-ball-joint-valve and the blowout preventer. The second embodiment may further comprise a tension ring with at least one tension member attached thereto, operatively attached to the first marine riser, and configured to place the first marine riser selectively in a state of increased or decreased tension; and a second tension ring with at least one tension member attached thereto, operatively attached to the secondDocket No. 689764.2021 / 67WO1 (TOFF-067 / 01 WO)FILED VIA EFS marine riser, and configured to place the second marine riser selectively in a state of increased or decreased tension.

[0009] In a third embodiment, the system may include: a transition riser joint configured to splice and intersect into a main riser to provide an inlet and thereby to provide an access or entry point into the main riser. The transition riser joint has a hollow body including a main branch having a main inlet at an upper portion thereof, the main branch being in fluid communication with a main outlet at a lower portion thereof. The main inlet is configured to sealingly connect to a first pipe joint of the main riser, and the main outlet is configured to sealingly connect, directly or via a second pipe joint of the main riser, to a blowout preventer. Thu the first pipe joint of the main riser is operatively connected to the blowout preventer through the transition riser joint. A middle riser joint is sealingly connected to the access inlet and includes an isolation valve (which may be a ball valve or another suitable valve). An upper riser joint is sealingly connected to and above the middle riser joint. The upper riser joint may include a distal device to close and seal upon a tube or wire such as a lubricator head, a rotating control device (RCD), or a similar device.. The isolation valve may be configured to be operated using its own independent control system or another suitable control system and controller. The isolation valve is configured to isolate the access inlet and other connected elements as disclosed herein or supplemental riser joints from the main wellbore (main riser) when desired or not in use. A work string such as a wireline or coiled tubing assembly may be guided and inserted into the lubricator (or a rotating control device) using a ROV (remotely operated vehicle) with a guide funnel or cone on top of the lubricator (or a rotating control device) for easy access / entry. The wireline or coiled tubing assembly may be lowered into the wellbore for performing the wireline (or coiled tubing) operations per the well plan. The apparatus may include a second pipe joint sealingly connected to the main outlet and to the blowout preventer, so that the main outlet of the transition riser joint is sealingly connected to the blowout preventer through the second pipe joint of the main riser. The inserted device may include at least one of a wireline, a coiled tubing assembly, a bottom hole assembly, or a drill string. The apparatus may comprise a guide funnel connected to the inlet of the upper riser joint and configured to guide the inserted device into the inlet of the upper riser joint. In some embodiments, the isolation valve opens and closes in response to signals from a dedicated controller sending signals only to the isolation valve. In some embodiments, the hollow body of the transition riser joint has connected thereto at least one of a booster line, a kill line, a choke line, a control cable, or an electrical cable. In any embodiment,Docket No. 689764.2021 / 67WO1 (TOFF-067 / 01 WO)FILED VIA EFS a main vessel may support the main riser, and the inserted device may pass through (at least a portion of) at least one of an auxiliary rotary, a moon pool of the main vessel, a side portion of the main vessel, or a second vessel. In certain embodiments, the transition riser joint is incorporated into a transition-riser-joint-carrier joint and is incorporated into a flange of the transition-riser-joint- carrier joint.

[0010] In a fourth embodiment, a method of drilling for hydrocarbons includes installing a wellhead assembly on or near a sea floor; connecting a blowout preventer to the wellhead assembly; connecting the blowout preventer to an articulating-rotating joint; connecting a Y-connector to the articulating-rotating joint, the Y-connector having: a lower trunk having a lower passage in fluid communication with a main outlet; a first upper branch with a first inlet in fluid communication with a first outlet, the first upper branch being configured to operatively couple to a first marine riser, and the first outlet being in fluid communication with the lower passage of the lower trunk; and a second upper branch with a second inlet in fluid communication with a second outlet, the second upper branch being configured to operatively couple to a second marine riser, and the second outlet being in fluid communication with the lower passage of the lower trunk, such that the articulating-rotating joint is configured and located to sealingly couple the lower trunk of the Y-connector to the blowout preventer; connecting the first inlet of the Y-connector to the first marine riser; connecting the second inlet of the Y-connector to the second marine riser; and conducting first drilling, wireline, or completions operations through the first marine riser while simultaneously assembling drilling, wireline, or completions equipment in the second marine riser in preparation for second drilling operations. The method may optionally include use of any system disclosed herein, including a system employing any combination of the optional features disclosed herein.

[0011] In a fifth embodiment, a method of drilling for hydrocarbons comprises: installing a wellhead assembly on or near a sea floor; connecting a blowout preventer to the wellhead assembly; connecting the blowout preventer to a main riser, the main riser including a least a first pipe joint; and operatively connecting an apparatus to the main riser. The apparatus includes a transition riser joint having a hollow body. The hollow body has a main branch having a main inlet at an upper portion thereof, the main branch being in fluid communication with a main outlet at a lower portion thereof. The main inlet is configured to sealingly connect to a first pipe joint of the main riser, and the main outlet is configured to sealingly connect to a the blowout preventer, so that the first pipe joint of the main riser is operatively connected to the second pipe joint of the main riser through theDocket No. 689764.2021 / 67WO1 (TOFF-067 / 01 WO)FILED VIA EFS transition riser joint. An access branch has an access inlet in fluid communication with the main outlet. The access branch is configured to sealingly connect to at least one middle riser joint separate from the main riser; at least one middle riser joint having a proximal end portion and a distal end portion, the proximal end portion being sealingly connected to the access inlet. At least one isolation valve may be sealingly connected to the middle riser joint to open or close a fluid path through at least a portion of the at least one middle riser joint to the main outlet of the hollow body of the transition riser joint. An upper riser joint is sealingly connected to the distal end portion of the middle riser joint. The upper riser joint has a proximal end portion, a distal end portion, an interior, an inlet, and the upper riser joint including a lubricator, wherein the lubricator is sealingly connected to the distal end portion of the upper riser joint. The lubricator an interior and an inlet configured to permit an inserted device to pass from an open subsea location through the lubricator, through the access branch, into the hollow body of the transition riser joint, and through the outlet of the hollow body of the transition riser joint, into the second pipe joint of the main riser. The lubricator is configured to sealingly engage the inserted device to seal the upper riser joint with respect to the open subsea location. The method further comprises conducting first drilling, wireline, completions, casing, cementing, or any well construction operations or coil tubing operations through the main riser while simultaneously assembling drilling, wireline, completions, casing, cementing, or any well construction equipment or coil tubing equipment in the open subsea location for insertion through the lubricator or a rotating control device, through the access branch, into the hollow body of the transition riser joint, and through the outlet of the hollow body of the transition riser joint, into the second pipe joint of the main riser in preparation for drilling, wireline, completions, casing, cementing, or any well construction operations, or coil tubing operations .BRIEF DESCRIPTION OF THE SEVERAL VIEWS OF THE DRAWINGS

[0012] The following detailed description will be better understood when read in conjunction with the appended drawings. Shown in the drawings are various embodiments, including embodiments which may be presently preferred. It should be understood, however, that the invention is not limited to the precise arrangements and instrumentalities shown. In the drawings:

[0013] Fig. 1 is schematic view of a dual-activity system according to the present disclosure;

[0014] Fig. 2 is an enlarged, partially schematic partial view of a first example of a Y connector for use in the dual-activity system of Fig. 1;Docket No. 689764.2021 / 67WO1 (TOFF-067 / 01 WO)FILED VIA EFS

[0015] Fig. 3 is an enlarged, partially schematic partial longitudinal sectional view of the Y connector of Fig. 2;

[0016] Fig. 4 is an enlarged, partially schematic partial view of a second example of a Y connector for use in the dual-activity system of Fig. 1;

[0017] Fig. 5 is a sectional, partially schematic view of the gate valve of the Y connector of Fig. 4, taken along the line 5-5 in Fig. 4;

[0018] Fig. 6 is a partially schematic elevational view of a second example of a dual-activity system according to the present disclosure in a first configuration with the first marine riser 1240 in a state of increased tension and the second marine riser 1260 in a state of decreased tension;

[0019] Fig. 7 is a partially schematic elevational view of a second example of a dual-activity system according to the present disclosure in a first configuration with the first marine riser 1240 in a state of decreased tension and the second marine riser 1260 in a state of increased tension;

[0020] Fig. 8 is a schematic view of a control system for operating components of a dualactivity system according to the present disclosure;

[0021] Fig. 9 is a schematic view of a third example of a dual-activity system according to the present disclosure;

[0022] Fig. 10 is an at least partially schematic view of a transition riser joint for use in a dualactivity system, with certain elements omitted for clarity; and

[0023] Fig. 11 is an at least partially schematic view of a lower lubricator joint for use in a dualactivity system;

[0024] Fig. 12 is an at least partially schematic view of a transition riser joint for use in a dualactivity system;

[0025] Fig. 13 is a schematic view of a second control system for operating components of a dual-activity system according to the present disclosure.DETAILED DESCRIPTION

[0026] Certain terminology is used in the following description for convenience only and is not limiting. The words “right,” “left,” “lower,” and “upper” designate directions in the drawings to which reference is made. The words “inner,” “inwardly,” “outer,” and “outwardly” refer to locations and directions toward and away from, respectively, the geometric center of an object and designated parts thereof. Unless specifically set forth otherwise herein, the terms “a,” “an,” andDocket No. 689764.2021 / 67WO1 (TOFF-067 / 01 WO)FILED VIA EFS“the” are not limited to one element but instead should be read as meaning “at least one.” “At least one” may occasionally be used for clarity or readability, but such use does not change the interpretation of “a,” “an,” and “the.” Moreover, the singular includes the plural, and vice versa, unless the context clearly indicates otherwise. As used herein, the terms “proximal” and “distal” are relative terms referring to locations or elements that are closer to (proximal) or farther from (distal) with respect to other elements, the user, or designated locations. “Including” as used herein means “including but not limited to.” The word “or” is inclusive, so that “A or B” encompasses A and B, A only, and B only. The terms “about,” “approximately,” “generally,” “substantially,” and like terms used herein, when referring to a dimension or characteristic of a component, indicate that the described dimension / characteristic is not a strict boundary or parameter and does not exclude minor variations therefrom that are functionally similar. At a minimum, such references that include a numerical parameter would include variations that, using mathematical and industrial principles accepted in the art (e.g., rounding, measurement or other systematic errors, manufacturing tolerances, etc.), would not vary the least significant digit thereof.

[0027] In one aspect, referring to Figs. 1-3, a system 100 for subsea drilling, wireline, or completions operations includes a Y-connector 180 including a hollow body 182. The Y-connector 180 has a lower trunk 184 having a lower passage 186 in fluid communication with a main outlet 188. The main outlet 188 may optionally include a protective sheath 210, which may take the form of a coating or a tubular element such as a sleeve, either of which may line the main outlet 188 to protect the main outlet main outlet 188 from abrasion, wear, or other damage as items pass through main outlet 188, as well as to protect the intersection of the main outlet 188 with the first outlet 194 and second outlet 200. A first upper branch 190 has a first inlet 192 in fluid communication with a first outlet 194, the first upper branch 190 being configured to operatively couple to a first marine riser 240, and the first outlet 194 being in fluid communication with the lower passage 186 of the lower trunk 184. A second upper branch 196 has with a second inlet 198 in fluid communication with a second outlet 200, the second upper branch 196 being configured to operatively couple to a second marine riser 260, and the second outlet 200 being in fluid communication with the lower passage 186 of the lower trunk 184. An articulating-rotating joint 160 is configured to sealingly couple the lower trunk 184 of the Y-connector 180 to a blowout preventer 140. The blowout preventer 140 in turn is operatively coupled to a wellhead assembly 120 located on or near the sea floor. Note that in Fig. 1, the first marine riser 240 and the second marine riser 260 are each madeDocket No. 689764.2021 / 67WO1 (TOFF-067 / 01 WO)FILED VIA EFS up a plurality of segments, and the relative lengths of the first marine riser 240 and the second marine riser 260 and the other elements depicted throughout the drawings are not proportional to one another. Each of the first marine riser 240 and the second marine riser 260 may include a slip joint 284 for attachment to the drilling platform 280, as is known in the art.

[0028] The first embodiment of the system 100 may include any combination of optional features discussed in this paragraph. The system 100 may further include a first isolation valve 202 disposed to open and close the first inlet 192; a second isolation valve 204 disposed to open and close the second inlet 198; and a third isolation valve 208 disposed to open and close the main outlet 188. A fourth isolation valve 206 may be disposed below the main outlet 188. The first isolation valve 202, the second isolation valve 204, and the third isolation valve 208 may be used to open and close paths for fluids and equipment leading from the first marine riser 240 and the second marine riser 260 to the articulating-rotating joint 160, and ultimately to the blowout preventer 140 and the wellhead assembly 120, so only one of the first marine riser 240 and the second marine riser 260 may connected with an open path to the blowout preventer 140 and the wellhead assembly 120 at a given time. The system may include the Y-connector 180 being configured to sealingly couple a selected one of the first upper branch 190 or the second upper branch 196 in fluid communication with the lower trunk 184. The articulating-rotating joint 160 may include a ball joint a spherical roller bearing (or similar) and packing elements, or a rotary seal to form a rotating-articulating joint. In the illustrated embodiment, the articulating-rotating joint 160 may include a housing 162 and a ball body 164 seated within the housing 162 for articulation and rotation with respect to the housing 162, wherein the ball body 164 is sealingly engaged with the housing 162 so that the articulating- rotating joint 160 provides a sealed connection joining the main outlet 188 of the Y-connector 180 to the blowout preventer 140. The ball body 164 may include an outlet 166 for sealingly engaging the outlet 166 with the blowout preventer 140. The system 100 may further include a seal 170 disposed between the housing 162 and the ball body 164.

[0029] Referring to Figs. 6-7, a subsea connector 340 may be provided to allow for hydraulic and / or electronic connection to an input device, including but not limited to a hydraulic or electrical connector or a remotely operated vehicle (ROV). A subsea connector 340 may also be incorporated into the system 100 of Fig. 1 by placing the subsea connector 340 in the system 100 in a location analogous to that shown in Figs. 6-7.Docket No. 689764.2021 / 67WO1 (TOFF-067 / 01 WO)FILED VIA EFS

[0030] The system 100 of Fig. 1 may include an alternative Y-connector 1180, as shown in Figs. 4 and 5. The Y-connector 1180 may include a first upper branch 1190, a second upper branch 1196 and a main outlet 1188. The first upper branch 1190 may have a first inlet 1192 and a first outlet 1194, and the second upper branch 1196 may have a second inlet 1198 and a second outlet 1200. The alternative Y-connector 1180 may further include a gate valve 1400 having a closure body 1402 movable by an actuator 1404. The closure body 1402 may be movable between a first position opening a path between the first inlet 1192 and the main outlet 1188 by aligning a first aperture 1406 in the closure body 1402 with the first upper branch 1190, and a second position opening a path between the second inlet 1198 and the main outlet 1188 by aligning the closure body 1402 with a second aperture 1408 in the closure body 1402. The first position of the closure body may close the path between the second inlet 1 198 and main outlet 1 188; and the second position of the closure body may close the path between the first inlet 1192 and the main outlet 1188. The closure body may take the form of a gate valve 1400 or similar components. The illustrated gate valve 1400 has a closure body 1402 selectably movable to block the first upper branch 1190 or the second upper branch 1196 and positioned by an actuator 1404. The actuator 1404 may by operatively connected to a controller 320, which may be as further described below. Note that although Fig. 4 shows the gate valve 1400 along with a first isolation valve 1202, a second isolation valve 1204, and a third isolation valve 1206, the gate valve 1400 may be used while omitting at least the first isolation valve 1202, the second isolation valve 1204, and the third isolation valve 1206.

[0031] The system 100 may further include a lubricator 300 operatively coupled to lubricate the articulating-rotating joint 160. The lubricator 300 may include an oil or grease reservoir with an accumulator or compensation system to provide lubrication to the articulating-rotating joint 160.The accumulator or compensation system of the lubricator 300 may be configured to compensate for a loss of lubrication due to usage and / or the water depth at which the equipment is operating. The lubricator 300 may have or be operatively connected to sensors for determining, for example, depth, level, pressure, or weight of lubricant, which may indicate the level of lubrication used or consumed and therefore the level of lubrication available in the reservoir of the lubricator 300. The lubricator 300 or the connected sensors may be operatively connected to trigger one or more alarms to alert an operator of the lubricator to the level of lubrication and / or a loss of lubrication.

[0032] Referring to Figs. 6-7, in a second embodiment, a system 1100 for subsea drilling, wireline, or completions operations may include a first marine riser 1240 configured to beDocket No. 689764.2021 / 67WO1 (TOFF-067 / 01 WO)FILED VIA EFS operatively coupled to a drilling platform 1280, which is equipped with two derricks 282, and a second marine riser 1260 configured to be operatively coupled to the drilling platform 1280. The first marine riser 1240 includes a first upper-riser segment 1242 and a first lower-riser segment 1244; the second marine riser 1260 includes a second upper-riser segment 1262 and a second lower- riser segment 1264. A third rotating-ball-joint-valve 1162 operatively connects the first marine riser 1240, and in particular the first lower-riser segment 1244, to the swivel body 1340. The third rotating-ball-joint-valve 1162 also operatively connects the second marine riser 1260, and in particular the second lower-riser segment 1264, to the swivel body 1340.

[0033] A first rotating-ball -joint-valve 1160 connects the first upper-riser segment 1242 to the first lower-riser segment 1244, such that the first upper-riser segment 1242 may rotate or articulate with respect to the first lower-riser segment 1244. Moreover, the first rotating-ball-joint-valve 1160 may be configured to operate as a valve so that when the first upper-riser segment 1242 is aligned with the first lower-riser segment 1244 as shown in Fig. 7, a path is open between first marine riser 1240 and the blowout preventer 140. A second rotating-ball-joint-valve 1160 connects the second upper-riser segment 1262 to the second lower-riser segment 1264, such that the second upper-riser segment 1262 may rotate or articulate with respect to the first lower-riser segment 1264. Moreover, the second rotating-ball-joint-valve 1160 may be configured to operate as a valve so that when the second upper-riser segment 1262 is aligned with the second lower-riser segment 1264 as shown in Fig. 6, a path is open between second marine riser 1260 and the blowout preventer 140.

[0034] Continuing to refer to Figs. 6 and 7, each of the first marine riser 1240 and the second marine riser 1260 has a tension device such as a tension ring 1250 operatively attached to the respective first upper-riser segment 1242 or second upper-riser segment 1262 thereof. The tension ring 1250 in each case at least one tension member 1252 attached thereto (two are shown) in a manner known to those of skill in the art. The tension members 1252 act on each tension ring 1250 to retract or release a selected one of the first marine riser 1240 or the second marine riser 1260 to place the selected one of the first marine riser 1240 or the second marine riser 1260 in tension, in turn resulting in the changes of configuration and alignment described above and shown in Figs. 6 and 7. That is, a tension ring 1250, the tension ring 1250 having at least one tension member 1252 attached thereto, is operatively attached to the first marine riser 1240 and configured to place the first marine riser 1240 selectively in a state of increased or decreased tension A second tension ring 1250, with at least one tension member 1252 attached thereto, is operatively attached to the secondDocket No. 689764.2021 / 67WO1 (TOFF-067 / 01 WO)FILED VIA EFS marine riser 1260 and configured to place the second marine riser 1260 selectively in a state of increased or decreased tension.

[0035] Note that in Figs. 6-7, the first marine riser 1240, the second marine riser 1260, first upper-riser segment 1242, first lower-riser segment 1244, second upper-riser segment 1262, and second lower-riser segment 1264 each may be made up a plurality of segments, as is known in the art. Moreover, the relative lengths of the first marine riser 1240 and the second marine riser 1260 and the other elements depicted throughout the drawings are not shown proportionally to one another; for example, the first marine riser 1240 and the second marine riser 1260 are proportionally far longer than the proportions shown. Each of the first marine riser 1240 and the second marine riser 1260 may include a slip joint 284 (as shown in the system 100 of Fig. 1) for attachment to the drilling platform 1280, as is known in the art.

[0036] In certain embodiments, the system 1100 may provide a second rotation path to the drilling platform 1280 in case the swivel body 1340 happens to fail. Each first upper-riser segment 1242 and second upper-riser segment 1262 would be held in tension by a tension ring 1250 and connected to the drilling platform 1280 by slip joint 284 (see Fig. 1). The rotating-ball-joint-valve 1162 is also able to pivot around its vertical axis (same as first marine riser 1240 in tension or second marine riser 1260 in tension) and that rotation would allow the drilling platform 1280 to rotate.

[0037] The system 1100 may include any combination of optional features discussed in this paragraph. At least one of the first rotating joint 1160, the second rotating joint 1160, the first rotating-ball-joint-valve 1160, may be configured for articulation as well as rotation. For example, at least one of the first rotating joint 1160, the second rotating joint 1160, the first rotating-ball-joint- valve 1160, or the second rotating-ball-joint valve 1160 may have a structure of the type disclosed with respect to the articulating-rotating joint 160.

[0038] Referring to Fig. 8, the system 100 may further include a controller 320 operatively coupled to at least one of the blowout preventer, the lubricator 300, the first isolation valve 202, the second isolation valve 204, the third isolation valve 208, or the actuator 1404 of the gate valve 1400 (Figs. 4 and 5).

[0039] Referring to Figs. 9-13, in further embodiments, disclosed is an apparatus 2000 adapted for subsea well construction or drilling using a main riser 2240, which is operatively connected to a drilling platform 2280 having at least one derrick 2282. The apparatus 2000 may include aDocket No. 689764.2021 / 67WO1 (TOFF-067 / 01 WO)FILED VIA EFS transition riser joint 2100 (sometimes called a TRJ) configured to provide an access path by splicing and intersecting into the main riser 2240 to allow an access or entry point into the main riser 2240. In certain embodiments, the main riser 2240 may be held in tension by a tension ring (as shown in Fig. 7 as element 1250) and connected to the drilling platform 2280 by a slip joint 2284 (see Fig. 9).

[0040] Referring to Figs. 9 and 10, the transition riser joint 2100 may include a hollow body 2182 (shown alone in Fig. 10) having a main branch 2196 having a main inlet 2198 at an upper portion of the hollow body 2182. The main inlet 2198 of the main branch 2196 may be at least generally aligned with the remainder of the main riser 2240. The main inlet 2198 is in fluid communication with a main outlet 2188 at a lower portion of the hollow body 2182. The main inlet 2198 is configured to sealingly connect to a first pipe joint 2260 of the main riser 2240, which may include sealingly connecting to the first pipe joint 2260 directly or sealingly connecting to the first pipe joint 2260 of the main riser 2240 through intervening elements such as one or more subsea connectors 2340 or one or more isolation valves 2204. The apparatus 2000 may include a plurality of first pipe joints 2260 as needed to reach a desired depth. The main outlet 2188 (Fig. 10) may be configured to sealingly connect to the blowout preventer 140 and may be configured to connect to the blowout preventer 140 directly or through a second pipe joint 2270, or a plurality of second pipe joints 2270, of the main riser 2240. Such sealing connection may include sealingly connecting to the second pipe joint 2270 directly or sealingly connecting to the second pipe joint 2270 of the main riser 2240 through intervening elements such as a subsea connector, additional second pipe joints 2270, or an isolation valve as disclosed elsewhere herein, so that the first pipe joint 2260 of the main riser 2240 is operatively connected to the blowout preventer 2240 through the transition riser joint 2100. A lower passage 2186 inside a lower projection 2184 connects the access outlet 2194 to the main outlet 2188. The lower passage 2186 may optionally include or be lined with a protective sheath 2210, which may take the form of a coating or a tubular element such as a sleeve, either of which may line the main outlet 2188 to protect the main outlet 2188 from abrasion, wear, or other damage as items pass through main outlet 2188, as well as to protect the intersection of the main outlet 2188 with the access outlet 2194 (discussed below).

[0041] An access branch 2190 has an access inlet 2192 in fluid communication and access outlet 2194, the first outlet 2194 being in fluid communication with the main outlet 2188 and providing a path into a lower portion of the main riser 2240, ultimately reaching the BOP stack or blowoutDocket No. 689764.2021 / 67WO1 (TOFF-067 / 01 WO)FILED VIA EFS preventer 140, the wellhead assembly 120, and the wellbore (not shown) below the BOP stack or blowout preventer 140.

[0042] The access branch 2190 is configured to sealingly connect to a middle riser joint 2400, the middle riser joint 2400 being separate from the main riser 2240. A plurality of middle riser joints 2400 may be employed to form an extended middle riser joint 2400 of convenient length. Thus the apparatus 2000 includes one or more middle riser joints 2400, each having a proximal end portion 2402 and a distal end portion 2404, the proximal end portion 2402 being sealingly connected to the access inlet 2192. One or more isolation valves 2410 are sealingly connected to the middle riser joint 2400 to open or close a fluid path through at least a portion of the middle riser joint 2400 to the main outlet 2188 of the hollow body 2182 of the transition riser joint 2100. The isolation valves 2410 may connect at either end of one of the middle riser joints 2400 or may be placed in an intermediate position between the ends of a middle riser joint 2400. Each isolation valve 2140 may be a ball valve or another suitable valve. Alternatively, and as noted above, the transition riser joint 2100 may also be installed and connected directly to the BOP stack or blowout preventer 140, thereby eliminating the need for a second pipe joint 2270.

[0043] The transition riser joint 2100, shown schematically at least partially in Figs. 9 and 10, may be incorporated into a transition-riser-joint-carrier joint 2120, as shown in Fig. 12. Referring to Fig. 12, the transition-riser-joint-carrier joint 2120 includes a pipe segment 2122 configured for connection into the main riser 2240 by way of flanges, seals, and other elements known in the art. The pipe segment 2122 may have attached, for example, to the exterior thereof, a flange 2130 for connecting to adjacent equipment, along with at least one booster line 2124, kill line 2126, choke line 2128, high-pressure hydraulic line, and / or control or electrical cables, as known in the art. In the example transition-riser-joint-carrier joint 2120, the access branch 2190 with the access inlet 2192 is attached to or incorporated into the transition-riser-joint-carrier joint 2120, passes through the flange 2130, and is configured for attachment to the middle riser joint 2400 (described further below). Alternatively, the access branch 2190 may connect as necessary without penetrating the flange 2130.

[0044] The middle riser joint 2400, shown schematically in Fig. 9, may be incorporated into a middle-riser-joint-carrier joint 2420, as shown in Fig. 11. Referring to Fig. 11, the middle-riserjoint-carrier joint 2420 includes a pipe segment 2422 configured for connection as part of the main riser 2240 by way of flanges, seals, and other elements known in the art. The pipe segment 2422Docket No. 689764.2021 / 67WO1 (TOFF-067 / 01 WO)FILED VIA EFS may have attached thereto at least one booster line 2424, kill line 2426, choke line, high-pressure hydraulic line, and / or control or electrical cables, as known in the art. In the example middle-riser- joint-carrier joint 2420, the middle riser joint 2400 is attached to the middle-riser-joint-carrier joint 2420 and is configured for attachment to the access inlet 2192 of the transition riser joint 2100. The middle riser joint 2400 may penetrate a flange 2430, as in the embodiment of Fig. 11. The lower outlet (not shown) of the middle-riser-joint-carrier joint 2420 connects to the access inlet 2192 of the transition-riser-joint-carrier joint 2120 to allow for the passage / access into the main riser 2240.

[0045] Referring to Fig. 9, an upper riser joint 2500 is sealingly connected to the distal end portion 2404 of the middle riser joint 2400 and may preferably be placed at least generally above the middle riser joint 2400 (including an extended middle riser joint comprising a plurality of middle riser joints 2400). The upper riser joint 2500 has a proximal end portion 2502, a distal end portion 2504, an interior 2508, and an inlet 2506. The upper riser joint 2500 includes a distal device 2600, which may be a lubricator, a rotating control device, or a similar sealing device creating an effective barrier to prevent sea water from entering the upper riser joint 2500. The distal device 2600 is sealingly connected to the distal end portion of the upper riser joint 2500 and may be integrally formed with the upper riser joint 2500. The distal device 2600 is configured to permit an inserted device 2800 to pass from an open subsea location 2700 below a sea surface 2702, through the distal device 2600, through the upper riser joint 2500, through the access branch 2190, into the hollow body 2182 of the transition riser joint 2100, through the main outlet 2188 of the hollow body 2182 of the transition riser joint 2100, into the second pipe joint 2270 of the main riser 2240. The distal device 2600 is configured to sealingly engage the inserted device 2800 to provide a sealing effect between the open subsea location 2700 and the interior 2508 of the upper riser joint 2500, preventing sea water from entering the apparatus 2000 or wellbore fluids from discharging into the environment. The inserted device 2800 may include at least one of a wireline, a coiled tubing assembly, a bottom hole assembly, or a drill string. The distal device 2600 forms a barrier between the sea water (on the outside of the system) and well construction fluids / muds (inside the riser joints).

[0046] The isolation valve 2410 may be configured to be operated using its own independent control system and controller (as defined elsewhere herein), or to be controlled by another controller operatively connected thereto, and may be used to isolate the access inlet 2192 and other connected elements as disclosed herein, or supplemental riser joints from the main wellbore or the main riserDocket No. 689764.2021 / 67WO1 (TOFF-067 / 01 WO)FILED VIA EFS2240 when desired or not in use. The inserted device 2800, for example wireline or coil tubing, may passes through at least one of an auxiliary rotary, a moon pool of the main vessel, from a side portion of the main vessel, or a second vessel, guided and inserted into the distal device 2800 (lubricator or a rotating control device) using a ROV (remotely operated vehicle) with a guide funnel 2900 or cone operatively connected to an upper end portion of the inserted device 2800 (lubricator or a rotating control device) for easy access / entry. After entering the main riser 2240 through the transition riser joint 2100, the inserted device 2800, such as a wireline or coiled tubing assembly, may be lowered into the wellbore for performing wireline (or coiled tubing) operations per the well plan.

[0047] The apparatus 2000 may further comprise a guide funnel 2900 connected to the inlet 2506 of the upper riser joint 2500 and configured to guide the inserted device 2800 into the inlet 2506 of the upper riser joint 2500.

[0048] The isolation valve(s) 2410 of the apparatus 2000 may open or close in response to signals from a controller such as the controller 2320 of Fig. 13, which may be a dedicated controller sending signals only to the isolation valve 2410; or the controller 2320 may include optional connections, shown as dashed lines in Fig. 13, to other system elements such as the blowout preventer 140, the distal device 2600, or the isolation valve(s) 2204.

[0049] Turning to methods of use of the systems disclosed herein, to the extent not otherwise inherent in the description thereof, in use, the system 100 may facilitate a method of drilling or well construction for hydrocarbons including the following steps: installing a wellhead assembly 120 on or near a sea floor; connecting a blowout preventer 140 to the wellhead assembly 120; connecting the blowout preventer to an articulating-rotating joint 160; connecting a Y-connector 180 to the articulating-rotating joint 160, the Y-connector 180 having: a lower trunk 184 having a lower passage 186 in fluid communication with a main outlet 188; a first upper branch 190 with a first inlet 192 in fluid communication with a first outlet 194, the first upper branch 190 being configured to operatively couple to a first marine riser 240, and the first outlet 194 being in fluid communication with the lower passage 186 of the lower trunk 184; and a second upper branch 196 with a second inlet 198 in fluid communication with a second outlet 200, the second upper branch 196 being configured to operatively couple to a second marine riser 260, and the second outlet 200 being in fluid communication with the lower passage 186 of the lower trunk 184, such that the articulating-rotating joint 160 is configured and located to sealingly couple the lower trunk 184 ofDocket No. 689764.2021 / 67WO1 (TOFF-067 / 01 WO)FILED VIA EFS the Y-connector 180 to the blowout preventer; connecting the first inlet 192 of the Y-connector to the first marine riser 240; connecting the second inlet 198 of the Y-connector to the second marine riser 260; and conducting first drilling wireline, or completions operations through the first marine riser 240 while simultaneously assembling drilling, wireline, or completions equipment in the second marine riser 260 in preparation for second drilling, wireline, or completions operations (or subsequent drilling, wireline, or completions operations). The method may optionally include use of any system disclosed herein, including a system employing any combination of the optional features disclosed herein.

[0050] Similarly, in use, the apparatus 2000 may facilitate a method of drilling or well construction for hydrocarbons including the following steps: installing a wellhead assembly 120 on or near a sea floor; connecting a blowout preventer 140 to the wellhead assembly 120; connecting the blowout preventer 140 to a main riser 2240, the main riser 2240 including a least one first pipe joint 2260 and optionally including second pipe joint(s) 2270; operatively connecting an apparatus 2000 to the main riser 2240. Alternatively, the transition riser joint 2100 may also be installed and connected directly to the BOP stack or blowout preventer 140, thereby eliminating the need for a second pipe joint 2270. The apparatus 2000 comprises a transition riser joint 2100 having a hollow body 2182, the hollow body 2182 having a main branch 2196 having a main inlet 2198 at an upper portion thereof, the main branch 2196 being in fluid communication via a main passage 2200 with a main outlet 2188 at a lower portion thereof, the main inlet 2198 being configured to sealingly connect to the first pipe joint 2260 of the main riser, and the main outlet 2188 being configured to sealingly connect to the blowout preventer 140, either directly or via one or more second pipe joints 2270 of the main riser 2240, so that the first pipe joint 2260 of the main riser 2240 is operatively connected to blowout preventer 140 through the transition riser joint 2100; and an access branch 2190 having an access inlet 2192 in fluid communication with the main outlet 2188, the access branch 2190 being configured to sealingly connect to at least one middle riser joint 2400 separate from the main riser 2240. The middle riser joint 2400 has a proximal end portion 2402 and a distal end portion 2404, the proximal end portion 2402 being sealingly connected to the access inlet 2192. At least one isolation valve 2410 is sealingly connected to the middle riser joint 2400 to open or close a fluid path through at least a portion of the middle riser joint 2400 to the main outlet 2188 of the hollow body 2182 of the transition riser joint 2100. An upper riser joint 2500 is sealingly connected to the distal end portion 2404 of the middle riser joint 2400, the upper riser joint 2500Docket No. 689764.2021 / 67WO1 (TOFF-067 / 01 WO)FILED VIA EFS having a proximal end portion 2502 and a distal end portion 2504. A distal device 2600, which may be a lubricator, a rotary control device, or a similar device (as described above) is sealingly connected to the distal end portion 2504 of the upper riser joint 2500 and may be integrally formed with the upper riser joint 2500. The distal device 2600 is configured to permit an inserted device 2800 to pass from an open subsea location 2700 through the distal device 2600, through the upper riser joint 2500, through the access branch 2190, into the hollow body 2182 of the transition riser joint 2100, through the main outlet 2188 of the hollow body 2182 of the transition riser joint 2100, into the second pipe joint 2270 of the main riser 2240. The distal device 2600 is configured to sealingly engage the inserted device 2800 to provide a sealing effect between the open subsea location 2700 and the interior 2508 of the upper riser joint 2500, preventing sea water from entering the apparatus 2000 or wellbore fluids from discharging into the environment. The inserted device 2800 may include at least one of a wireline, a coiled tubing assembly, a bottom hole assembly, or a drill string which may be run thru the auxiliary rotary, moon pool, from the side of the vessel or a separate vessel.

[0051] The distal device 2600 forms a barrier between the sea water (on the outside of the system) and well construction fluids / muds (inside the middle riser joint 2400, upper riser joint 2500, or the main riser 2240). A further step comprises conducting first drilling, wireline, completions, casing, cementing, or any well construction operations or coil tubing operations through the main riser 2240 while simultaneously assembling drilling, wireline, completions, casing, cementing, or any well construction equipment, or coil tubing equipment in the open subsea location 2700 for insertion through the distal device 2600, through the access branch 2190, into the hollow body 2182 of the transition riser joint 2100, and through the main outlet 2188 of the hollow body 2182 of the transition riser joint 2100, into the second pipe joint 2270 of the main riser 2240 in preparation for second drilling, wireline, completions, casing, cementing, or any well construction operations or coil tubing operations .

[0052] The Y-connector 180, the housing 162 and the ball body 164 of the articulating-rotating joint 160, the swivel body 1340, the first rotating joint 1160, the second rotating joint 1160, the first rotating-ball-joint-valve 1160, or the fourth-rotating joint 1160, the first upper-riser segment 1242, the first lower-riser segment 1244, the second upper-riser segment 1262, and the second lower-riser segment 1264 and other components of the systems may be formed from a strong, corrosionresistant materials such as composites (including composites having carbon fiber), polymers, non-Docket No. 689764.2021 / 67WO1 (TOFF-067 / 01 WO)FILED VIA EFS metallics, metallics (including but not limited to low carbon steel) which may be protected by a suitable coating. The first rotating-ball-joint-valve 1160, or the fourth-rotating joint 1160, the first upper-riser segment 1242, the first lower-riser segment 1244, the second upper-riser segment 1262, and the second lower-riser segment 1264 may be formed of elastic material such as polymers or composites, which may be selected so that longitudinal elastic deformation of the first rotating-ball- joint-valve 1160, or the fourth-rotating j oint 1160, the first upper-riser segment 1242, the first lower- riser segment 1244, the second upper-riser segment 1262, and the second lower-riser segment 1264 may constitute a length-compensation mechanism. The seal 170 may be formed from durable sealing material such as rubber, polyurethane, silicone, metal, elastomer or composites. Other components, such as the wellhead assembly 120, the blowout preventer 140, the first isolation valve 202, the second isolation valve 204, the third isolation valve 208, the first marine riser 240, the second marine riser 260, the drilling platform 280, 1280, the controller 320, and other components are made from materials generally known to those of skill in the art.

[0053] With respect to the methods and processes described herein, those skilled in the art will recognize that boundaries between the above-described operations are merely illustrative. The multiple operations may be combined into a single operation, a single operation may be distributed in additional operations and operations may be executed at least partially overlapping in time. Further, alternative embodiments may include multiple instances of a particular operation, and the order of operations may be altered in various other embodiments.

[0054] It will be appreciated by those skilled in the art that changes could be made to the embodiments described above without departing from the broad inventive concept thereof. It is understood, therefore, that this invention is not limited to the particular embodiments disclosed, but it is intended to cover modifications within the spirit and scope of the present disclosure.

Claims

Docket No. 689764.2021 / 67WO1 (TOFF-067 / 01 WO)FILED VIA EFSCLAIMSWe claim:

1. An apparatus adapted for subsea well construction or drilling using a main riser, the apparatus comprising: a transition riser joint having a hollow body, the hollow body having: a main branch having a main inlet at an upper portion thereof, the main branch being in fluid communication with a main outlet at a lower portion thereof, the main inlet being configured to sealingly connect to a first pipe joint of the main riser, and the main outlet being configured to sealingly connect to a blowout preventer so that the first pipe joint of the main riser is operatively connected to the blowout preventer through the transition riser joint; and an access branch having an access inlet in fluid communication with the main outlet, the access branch being configured to sealingly connect to a middle riser joint separate from the main riser; a middle riser joint having a proximal end portion and a distal end portion, the proximal end portion being sealingly connected to the access inlet; an isolation valve sealingly connected to the middle riser joint to open or close a fluid path through at least a portion of the middle riser joint to the main outlet of the hollow body of the transition riser joint; an upper riser joint sealingly connected to the distal end portion of the middle riser joint, the upper riser joint having a proximal end portion, a distal end portion, an interior, an inlet, and the upper riser joint including a distal device, wherein the distal device is sealingly connected to the distal end portion of the upper riser joint; wherein the distal device has an interior and an inlet configured to permit an inserted device to pass from an open subsea location through the distal device, through the access branch, into the hollow body of the transition riser joint, and through the main outlet of the transition riser joint, into the blowout preventer; andDocket No. 689764.2021 / 67WO1 (TOFF-067 / 01 WO)FILED VIA EFS wherein the distal device is configured to sealingly engage the inserted device to seal the upper riser joint with respect to the open subsea location.

2. The apparatus according to claim 1, further comprising a second pipe joint sealingly connected to the main outlet and to the blowout preventer, so that the main outlet of the transition riser joint is sealingly connected to the blowout preventer through the second pipe joint of the main riser.

3. The apparatus according to claim 1 or claim 2, wherein the inserted device includes at least one of a wireline, a coiled tubing assembly, a bottom hole assembly, or a drill string.

4. The apparatus according to any one of claims 1-3, further comprising a guide funnel connected to the inlet of the distal device and configured to guide the inserted device into an inlet of the distal device .

5. The apparatus according to any one of claims 1-4, wherein the isolation valve opens and closes in response to signals from a controller.

6. The apparatus according to claim 5, wherein the isolation valve opens and closes in response to signals from a dedicated controller sending signals only to the isolation valve.

7. The apparatus according to any one of claims 1-6, wherein the hollow body of the transition riser joint has connected thereto at least one of a booster line, a kill line, a choke line, a control cable, or an electrical cable.

8. The apparatus according to any one of claims 1-7, wherein a main vessel supports the main riser, and wherein the inserted device passes through at least one of an auxiliary rotary, a moon pool of the main vessel, from a side portion of the main vessel, or a second vessel.

9. The apparatus according to any one of claims 1-8, wherein the transition riser joint is incorporated into a transition-riser-joint-carrier joint and is incorporated into a flange of the transition- riser-j oint-carrier j oint.

10. The apparatus according to any one of claims 1-9, wherein the distal device comprises at least one of a lubricator or a rotating control device.

11. A method of drilling for hydrocarbons, comprising: installing a wellhead assembly on or near a sea floor;Docket No. 689764.2021 / 67WO1 (TOFF-067 / 01 WO)FILED VIA EFS connecting a blowout preventer to the wellhead assembly; connecting the blowout preventer to a main riser, the main riser including a least a first pipe joint; operatively connecting an apparatus to the main riser, the apparatus comprising: a transition riser joint having a hollow body, the hollow body having: a main branch having a main inlet at an upper portion thereof, the main branch being in fluid communication with a main outlet at a lower portion thereof, the main inlet being configured to sealingly connect to a first pipe joint of the main riser, and the main outlet being configured to sealingly connect to the blowout preventer, so that the first pipe joint of the main riser is operatively connected to the blowout preventer through the transition riser joint; and an access branch having an access inlet in fluid communication with the main outlet, the access branch being configured to sealingly connect to a middle riser joint separate from the main riser; a middle riser joint having a proximal end portion and a distal end portion, the proximal end portion being sealingly connected to the access inlet; an isolation valve sealingly connected to the middle riser joint to open or close a fluid path through at least a portion of the middle riser joint to the main outlet of the hollow body of the transition riser joint; an upper riser joint sealingly connected to the distal end portion of the middle riser joint, the upper riser joint having a proximal end portion, a distal end portion, an interior, an inlet, and the upper riser joint including s distal device, the distal device comprising at least one of a lubricator or a rotating control device, wherein the distal device is sealingly connected to the distal end portion of the upper riser joint; wherein the distal device has an interior and an inlet configured to permit an inserted device to pass from an open subsea location through the distal device,Docket No. 689764.2021 / 67WO1 (TOFF-067 / 01 WO)FILED VIA EFS through the access branch, into the hollow body of the transition riser joint, and through the main outlet of the transition riser joint, into the blowout preventer; and wherein the distal device is configured to sealingly engage the inserted device to seal the upper riser joint with respect to the open subsea location; and conducting first drilling, wireline, completions, casing, cementing, well construction operations, or coil tubing operations through the main riser while simultaneously assembling equipment for second drilling, wireline, completions, casing, cementing, well construction operations or, coil tubing operations in the open subsea location for insertion through the distal device, through the access branch, into the hollow body of the transition riser joint, and through the main outlet of the transition riser joint, into the second pipe joint of the main riser in preparation for second drilling, wireline, completions, casing, cementing, or any well construction operations, or coil tubing operations.

12. The method of drilling for hydrocarbons according to claim 11, wherein the method comprises use of a system according to any one of claims 2-10.

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