Manifold string for selectivity controlling flowing fluid streams of varying velocities in wells from a single main bore

Abstract

A set of manifold string members usable to selectively control separate flowing fluid streams of varying velocities for operations of well construction, injection or production of fluid mixtures of liquids, gases and/or solids, that can be injected into, or taken from, one or more proximal regions of a subterranean passageway, underground cavern, hydrocarbon or geothermal reservoir. Fluid communicated through a manifold string radial passageway of a manifold crossover, between conduit strings and at least one other conduit, can be controlled with at least one flow controlling member, communicating with a passageway member from an innermost, concentric, and/or annular passageway. Fluid communication can be selectively controlled for various configurations of one or more substantially hydrocarbon and/or substantially water wells, below a single main bore and wellhead.

Claims

1. A method of using a set of subterranean manifold string (49, 70, 76) members for selectively controlling separate injected and extracted continuous, simultaneously flowing fluid mixture (38) streams (31-37) of varying velocities within one or more subterranean wells during drilling and production operations, extending from a single main bore (6) and wellhead (7), comprising the steps of: providing, at an upper end of said one or more subterranean wells, a subterranean disposed manifold string (49, 70, 76) member with a plurality of member conduit strings (2, 2A, 2B, 2C, 39, 50, 51, 71, 78), wherein said manifold string member is rotatably installed and engagable with a concentric bore wellhead (7); providing at least one manifold crossover (23) member with at least one radial passageway (75) member in fluid communication with at least one passageway (24, 24A, 24B, 25, 26, 53, 54, 55) member into communication with at least one of the plurality of member conduit strings extending axially downward from said at least one manifold crossover member to at least one proximal region of said one or more subterranean wells; and selectively controlling said separate simultaneously flowing fluid streams of varying velocities between said concentric bore wellhead and said at least one proximal region using one or more flow controlling members (61) engaged between said plurality of member conduit strings, or placeable through innermost passageway (25) members or innermost passageway member connectors (26) of said at least one manifold crossover member, and engagable to at least one receptacle member placed between said plurality of member conduit strings or within said at least one manifold crossover member, thereby urging substantially subterranean hydrocarbon or substantially water fluid mixtures of liquids, gases, solids, or combinations thereof, to or from said at least one proximal region.

2. The method of claim 1, wherein a first flow controlling member comprising a concentric bore valve tree (10, 10A) is engaged to an upper end of said concentric bore wellhead for selectively controlling injected or extracted flow streams usable for communicating with at least a second subterranean disposed flow controlling member and measuring or controlling at least a portion of fluid communicated through said at least one passageway member.

3. The method of claim 1, wherein said one or more flow controlling members comprise a subterranean placeable apparatus (61) for blocking all or part of said at least one passageway member during or after subterranean installation of said manifold string.

4. The method of claim 3, further comprising the step of selectively diverting at least a portion of a flow stream (31-38) through a smaller effective diameter passageway member to form a proximal length of velocity string or venturi arrangement (85) with a smaller effective diameter passageway member relative to the volume of flow.

5. The method of claim 3, further comprising the step of selectively separating a fluid mixture flow stream within a space of said at least one passageway member into at least two separate streams (31-37) of varying velocities comprising substantially liquid, substantially gas, or substantially water, by selectively affecting the velocity and containing pressure exerted on at least one of said separate streams.

6. The method of claim 5, further comprising the step of providing a gas lift arrangement (70, 70D, 76) and injecting a separate substantially gaseous flow stream into a substantially liquid flow stream through at least one additional flow controlling gas lift valve (84) member engaged between said plurality of member conduit strings or in said at least one receptacle comprising a side pocket mandrel.

7. The method of claim 1, further comprising the step of using an adapted managed pressure conduit assembly (49) member and an adapted slurry passageway apparatus member (58) to place other manifold string members between said concentric bore wellhead and said at least one proximal region to form said one or more subterranean wells below the single main bore.

8. The method of claim 1, further comprising the step of providing said one or more flow controlling members (61) using cable conveyed rotary operations apparatus selectively placeable within the innermost passageway members or engagable to said at least one receptacle (45, 45A) via cable conveyance during or after subterranean installation of said manifold string, wherein a submersible electrical motor, fluid motor driven pump, or piston with a fluid inlet and a fluid outlet communicates with regions of said separate simultaneously flowing fluid streams of varying velocities and pressures, whereby said fluid motor driven pump or piston is operable by differential fluid pressure between said separate simultaneously flowing fluid streams of varying velocities provided by said at least one passageway member.

9. The method of claim 8, further comprising the step of engaging the submersible electric motor (111) or fluid motor driven pump (69) to said at least one receptacle (45, 45A) or between said plurality of member conduit strings, to electrically rotate the submersible electric motor, or use said differential fluid pressure in conjunction with the fluid motor drive pump, to rotate a turbine motor, a positive displacement motor, or combinations thereof, to operate a fluid impellor (112) pump, a positive displacement (108, 109) pump, or combinations thereof to urge fluid mixture flow within said at least one passageway member.

10. The method of claim 1, wherein the step of providing a manifold crossover member (23) further comprises communicating fluid from at least one first innermost passageway member (25, 26) through at least a second passageway member (24, 24A, 24B, 53, 54, 55) to at least a third passageway member (24, 24A, 24B, 53, 54, 55), wherein a bore selector (47) or other flow controlling member, placed through said at least one first innermost passageway member (25, 26) extending from said concentric bore wellhead (7), enables fluid communication between said at least one innermost passageway member and said at least a third passageway member.

11. The method of claim 1, further comprising the step of utilizing a first flow stream (31-38) or subsurface thermal sink to thermally affect a second flow stream (31-38).

12. A subterranean flow controlling member apparatus of a manifold string (49, 70, 76) that is engagable with a concentric bore wellhead (7), wherein said manifold string is usable for selectively controlling separate injected and extracted continuous, simultaneously flowing fluid mixture streams (31-37) of varying velocities within one or more subterranean wells during drilling and production operations, extending from a single main bore (6) and wellhead (7), comprising: a flow controlling member (21, 23, 43, 43A, 47, 47A, 49, 51A, 58, 69, 70, 76, 7, 10, 16, 22, 25A, 63, 64, 66, 74, 77, 84, 85, 91, 96, 97, 108-112, 115, 116, 123) engagable between conduits of conduit member strings (2, 2A, 2B, 2C, 39, 50, 51, 71, 78) or placeable through innermost passageway members (25, 26, 53) of said conduit member strings and engagable to at least one receptacle (45, 45A), wherein the flow controlling member is positioned between said concentric bore wellhead at an upper end of said one or more subterranean wells and at least one proximal region of said one or more subterranean wells, and wherein the flow controlling member comprises at least one radial passageway (75) member for providing fluid communication between a first and a second passageway member of the plurality of conduit member strings and the one or more subterranean wells; and wherein said flow controlling member is rotatably installed, and engagable to said concentric bore wellhead or placeable between said concentric bore wellhead and said at least one proximal region to selectively control at least one flowing fluid mixture stream (31-38) communicated through said passageway members (24, 24A, 24B, 25, 26, 53, 54, 55) to urge said at least one flowing fluid mixture stream to or from said at least one proximal region and at least one more proximal region or to said concentric bore wellhead.

13. The flow controlling member apparatus of claim 12, further comprising a placeable and removable motor and fluid pump (69), engagable between said conduit member strings or within said passageway members or said at least one receptacle with a cable (11) or a connector (68) through said innermost passageway members of said one or more subterranean wells, usable to pump at least one fluid mixture stream (31-38) within at least one of said passageway members during construction, operation of a substantially subterranean hydrocarbon or substantially water well, or combinations thereof.

14. The flow controlling member apparatus of claim 13, wherein a first of said separate simultaneously flowing fluid mixture streams rotates at least one fluid turbine (112) motor, a positive displacement (108, 109) motor, or combinations thereof, wherein said at least one fluid turbine (112) motor, said positive displacement (108,109) motor, or combinations thereof are engaged to a shaft, wherein the shaft is usable to rotate at least one associated fluid impellor (112) pump, positive displacement (108, 109) pump, or combinations thereof, to urge said at least one fluid mixture stream using the velocity or pressure of at least a second fluid mixture stream within at least a second passageway member.

15. The flow controlling member apparatus of claim 13, further comprising a submersible electric motor (111) for rotating at least one fluid impellor (112) pump, positive displacement (108, 109) pump, or combinations thereof, to urge said at least one fluid mixture stream within at least one of said passageway members, wherein connections (110) for said submersible electric motor are disposed within said conduit member strings, engagable to said submersible electrical motor, and wherein said submersible electric motor is placeable between said conduit member strings or through said passageway members.

16. The flow controlling member apparatus of claim 12, further comprising a fluid mixture flow stream blocking device engagable to at least one other manifold string member to control fluid communication of at least one passageway member affecting at least one of said separate simultaneously flowing fluid streams of varying velocities during construction, operation of a substantially hydrocarbon or substantially water well, or combinations thereof.

17. The flow controlling member apparatus of claim 12, further comprising a flow stream fixed choke or variable opening fluid communication device engagable to at least one other manifold string member to control the velocity or pressure of at least one of said separate simultaneously flowing fluid streams of varying velocities.

18. The flow controlling member apparatus of claim 12, further comprising measurement devices, controlling devices, signal devices, or combinations thereof, for measuring a pressure, velocity or temperature with mechanical or fluid linkages, pulses or control cables engaged to or placeable through a member to said at least one proximal region to selectively control at least a second flow controlling member apparatus usable to control said separate simultaneously flowing fluid mixture streams of varying velocities.

19. The flow controlling member apparatus of claim 12, further comprising a bore selector member (47) for controlling fluid communication within one or more passageway members extending from a chamber junction, wherein placement of the bore selector member is aided by at least one of said separate simultaneously flowing fluid streams exerting pressure on a guide surface (87), to selectively communicate fluid mixtures between passageway members disposed axially along said manifold string.

20. The flow controlling member apparatus of claim 19, wherein the bore selector member comprises at least a second flow controlling member to further aid bore selector placement, fluid mixture communication, or combinations thereof.

Description

BRIEF DESCRIPTION OF THE DRAWINGS

(1) Preferred embodiments of the invention are described below by way of example only, with reference to the accompanying drawings, in which:

(2) FIGS. 1, 2 and 3 depict conventional hydrocarbon/water, solution mining/underground storage wells and a wireline rig, respectively, with a reconfigured arrangement forming an embodiment of the present invention shown under FIG. 1.

(3) FIGS. 4, 5 and 5A depict prior art diagrams of hydrocarbon pressure flow rate, bubble point, and sandface pressure versus mass rate functions, respectively.

(4) FIGS. 6 to 7 illustrate an embodiment of a manifold string arranged to selectively vary the length of an internal velocity string.

(5) FIGS. 8 to 19 and 20 to 21, depict various embodiments of a manifold crossover and adapted chamber junction usable with manifold crossovers, respectively.

(6) FIGS. 22 to 25 show the manifold crossover members of FIG. 10 to 13 or 14-16 with a blocking flow controlling member installed within an internal receptacle.

(7) FIGS. 26 to 29 illustrate an embodiment of a fluid motor and pump flow controlling member engaged within the manifold crossover of FIGS. 10 to 16.

(8) FIGS. 30 to 35 depict the fluid motor and pump flow controlling member of FIGS. 36 to 37 disposed within an embodiment of a manifold crossover.

(9) FIGS. 36 to 37 show an embodiment of a fluid motor and pump flow controlling member.

(10) FIGS. 38 to 39 illustrate alternative motor and pump member arrangements usable in an embodiment of a fluid motor and pump flow controlling member.

(11) FIGS. 40, 41 and 46-47 depict a conventional waste disposal well, hydrocarbon separation and gas lift arrangements, respectively.

(12) FIGS. 42 to 45 and 48 to 52 depict various embodiments within a manifold string member set.

(13) FIG. 53 shows a subsea wellhead and chamber junction arrangement usable with the manifold string of FIG. 59.

(14) FIGS. 54 to 57 illustrate embodiments of a manifold crossover with radial passageways usable to convert the chamber junction of FIG. 58 to the manifold string of FIG. 59.

(15) FIGS. 58 to 59 depict a chamber junction and a manifold string member embodiment, respectively, formed by adapting the chamber junction of FIG. 58 with the manifold crossover member of FIGS. 54 to 57.

(16) FIGS. 60 to 61 and FIGS. 62 to 66, show a chamber junction and manifold string member embodiment adapted from said chamber junction, respectively, and usable for simultaneous injection and production.

(17) FIGS. 67, 67A and 68 illustrate various valve flow controlling member and crossover member arrangement embodiments, used in various manifold string members, usable with still other members of the set of manifold string members.

(18) FIGS. 69 to 75 depict various embodiments of manifold crossover members usable with adapted chamber junctions to form manifold siring members.

(19) FIGS. 76 to 80 show an adapted chamber junction member usable with the manifold crossover member of FIGS. 73 to 75.

(20) FIG. 81 illustrates a conduit member usable between the manifold crossover of FIGS. 73 to 75 and the adapted chamber junction of FIGS. 76 to 80.

(21) FIG. 82 depicts an embodiment of a manifold string member, formed by combining the member parts of FIGS. 73 to 81, usable with other members to form the embodiment of FIGS. 106-116.

(22) FIGS. 83 to 87 show an embodiment of a manifold member, of a chamber junction manifold crossover, adapted to form lower frictional flow stream member passageways with a blocking and diversional flow controlling member engaged within an associated receptacle.

(23) FIGS. 88 to 89 and FIG. 90 illustrate chamber junction and bore selector members, respectively, usable with embodiments of the present invention.

(24) FIG. 91, FIG. 92, FIG. 93, FIG. 93A and FIG. 94, depict prior art valve, packer, plug, straddle and nipple flow controlling members, respectively.

(25) FIGS. 95 to 96, show a bore selector member usable with adapted chamber junction embodiments of the present invention.

(26) FIGS. 97 to 99 and 100 to 105 show an adapted chamber junction and manifold string member embodiment, respectively formed from a managed pressure conduit string assembly.

(27) FIGS. 106 to 116, illustrate an embodiment of a junction of wells manifold string for a plurality of wells from a single main bore.

(28) FIGS. 117, 118 and 119 to 122 illustrate a chamber junction crossover, bore selector and various manifold string member embodiments, respectively, usable for accessing different concentric passageways from the innermost passageway.

(29) FIG. 123 shows an embodiment of a diagrammatic manifold string member, with a plurality of wells extending from a junction of wells, configurable to control flow streams in hydrocarbon, water and/or underground storage wells simultaneously to perform various well formation, operation and/or processing functions.

(30) Embodiments of the present invention are described below with reference to the listed Figures.

DETAILED DESCRIPTION OF THE EMBODIMENTS

(31) Before explaining selected embodiments of the present invention in detail, it is to be understood that the present invention is not limited to the particular embodiments described herein and that the present invention can be practiced or carried out in various ways.

(32) Referring now to FIGS. 1 to 5, various conventional well configurations and fluid dynamic methodical functions for substantially hydrocarbons and/or substantially water fluid mixtures that can be injected into or produced from a reservoir, are depicted. The fluid mixtures also can be injected into or produced from underground storage or salt dissolution spaces using conventional single flow systems in addition to simultaneously flowing fluid streams and various well configurations.

(33) Despite the use of conventional apparatus between hydrocarbon, water and under storage wells, very few practical applications relating to the use of simultaneously flowing fluids, used during solution mining and/or operation of an underground storage cavern, have been adopted by hydrocarbon well artisans.

(34) Growth in demand and decreases in the economic return and size of conventional discoveries have increased the need for new technologies, which are usable to increase the volume of hydrocarbons recovered from both conventional and unconventional reservoirs, for example tar sands and shale gas reservoirs. Innovations in the use of separately and simultaneously flowing fluid streams, of varying velocity, to enhance production, dispose of wastes, and/or to perform underground storage are becoming more economically applicable to hydrocarbons, thereby increasing the applicability of developing off-the-shelf well construction, production, injection and processing members of a compatible set, which are analogous to building blocks and combinable in various arrangements, configurations, and/or orientations to enhance substantially hydrocarbon and substantially water operations, such as geothermal, waste disposal, solution mining, and storage, well operations.

(35) Additionally, large scale hydrocarbon tar sands and shale gas reservoirs are currently considered unconventional sources, due to the difficulties in developing such reserves with current technology. However, embodiments of the present invention provide technologies for increasing the efficiency of heat transfer and fracture propagation, below a single main bore, to decrease the viscosity or to increase the effective permeability of unconventional tar sand and shale gas reservoirs, thereby further justifying development of off-the-shelf simultaneous flow stream technology to transition such reserves into a conventional reserves category.

(36) FIGS. 1 and 2 depict an elevation diagrammatic cross section view of a conventional subterranean well, that can be usable for hydrocarbon/water/storage and solution mining wells, respectively. The Figures illustrate conventional flow control devices in addition to presenting flow controlling members of a manifold string member set, comprising a wellhead (7) and valve tree (10) with surface valves (64) engaged to casings (3, 14, 15) that extend through a bore through strata (17) and, together, comprise a passageway through subterranean strata (52). A manifold string embodiment (70M of FIG. 1) can be formed by adapting the conventional well depicted at the top of FIG. 1 and is illustrated with a process diagram at the bottom of FIG. 1. Manifold string embodiments (70P of FIGS. 1 and 70N of FIG. 2) can be formed by adapting the conventional wells of FIG. 1 and FIG. 2 with the addition of a flow controlling member (21 of FIGS. 117-122). A similar completion (2, 40, 61, 10) to FIG. 1 is commonly used after the solution mining (1) configuration of FIG. 2 is removed for underground storage within the walls of a salt cavern (1A).

(37) Where conventional practice for applications involving apparatus, such as sliding side doors (123), jet pumps (85), frac sleeves and gas lift valves, may form simultaneously flowing fluid streams, the applications of such practices across various well types are limited; and therefore, prevent standardization of a member set of apparatus and methods, usable to form readily available off-the-shelf applications that are coveted by well construction practitioners and operators.

(38) Embodiments of the present invention can be combined with conventional apparatus. For example, a valve tree (10A of FIG. 2), jet pump (85) and concentric conduit (2A or 3), that is suited for simultaneously flowing fluid mixtures (38) and circulating water with a pump (116), are usable to form the member embodiment (70M) of FIG. 1 or the member embodiment (70N) of FIG. 2, along with the addition of a chamber junction manifold crossover (21) embodiment to the well.

(39) Generally, for the hydrocarbon, water, and storage wells depicted in FIGS. 1 and 2, flow streams of approximately the same velocity, using mono-bore strings and/or completions of approximately the same internal diameter, that are conducive with common flow stream velocities, occur through the innermost tubing string (2) passageway (25), controlled by a subterranean valve (74) in instances where escape of subterranean pressures is a risk, as shown in FIG. 1.

(40) FIG. 1, shows the subterranean valve (74) and packer (40) flow controlling members (61) controlling the adjacent concentric passageways (24, 54) with a sliding side door (123) or a jet pump (85) controlling communication between the passageways (24, 54) and the casing shoes (16). The sealed annular spaces can be monitored with annuli gauges (13) to confirm well pressure integrity, between a fluid mixture (38) entering or exiting the tubing at the well's lower end and exiting (34) or being injected (31) into the valve tree (10) at the well upper end. The concentric passageways (54) are not generally designed for continuous flow of production or injected fluids, except in special instances, such as the using of a sliding side door (123) to change annulus fluids, the supply of jet pump (85) water, or in instances later described in FIGS. 40-41 and 46-47.

(41) The conventional jet pump reconfiguration of the FIG. 1 well, uses the annulus between the tubing (2) and the final cemented casing (3) to provide water for a venturi (85) (referred to as a jet pump), that is placed within the tubing. When using a conventional jet pump, the utility of this approach may be limited as, water combined with the produced fluid mixture (38) stream and must later be removed. However, the depicted embodiments (70M, 70P) form separate flow stream velocities in singular flow stream applications, such as velocity strings of selectively controllable length, and/or forms a plurality of separate flow streams, for example in jet pump applications and downhole processing.

(42) Embodiments of the present invention include, jet pump applications that form separate simultaneously flowing fluid streams of varying velocity to urge production. For example, the manifold string member (70M) embodiment, depicted at the bottom of FIG. 1, is formed using the final cemented casing (3) and valve tree (10) of FIG. 1, or the valve tree (10A) of FIG. 2 and associated wellhead (7), for inclusion of a concentric string (2A) between the tubing (2) and the final cemented casing (3). This forms a circulation pathway between the concentric string member (2A), or final cemented casing member (3) and the inner string (2) member, to form a pumped (116) closed system with a high-velocity, continuously-circulated, flow stream connected, via a venturi (85), to the tubing (2). A portion of the production is sucked from the tubing (2) to create a vacuum venturi effect for removing hydrostatic pressure from a first produced fluid mixture flow stream to further urge its production (34), while urging a second flow stream produced with pumped (116) water and separated at a circulating system tank. The circulating tank separates the portion of second flow stream produced fluid mixture into a liquid stream (119), that is taken from between the water contact (117) and the liquid contact (118). In addition, a gas stream (120) can be taken from the circulation tank upper end. The circulating fluid may be reused or replaced, with the circulated liquid typically being treated water, other mixtures of liquids, gases and/or solids as applicable.

(43) Traditionally, jet pumps are generally used in water flooded or sweep reservoir applications with high water cuts, wherein water handling facilities limit their application. However, embodiments of the present invention can include vacuuming the hydrocarbon portion of the production with a device, such as the venturi, so that later separation of the fluids within the circulating tank will be generally small, as will be the impact of limited water handling facilities.

(44) The arrangement of apparatus in FIG. 1 can also be applicable to underground storage wells, wherein the final cemented casing (3) shoe (16) can be a flow controlling member for products stored within the cavern walls (1A). A manifold string member (70P) embodiment can be formed with the addition of a chamber junction crossover (21) member and associated conduit (2, 2A) members, that can be usable to selectively access and flow separate, simultaneous fluid streams of gravity-separated products, such as crude oil and liquid natural gas (LNG), that is floating above the oil and brine within a salt cavern walls (1A). The separate and simultaneous flow streams can be used to selectively displace the gravity-separated products within the cavern by selectively placing a bore selector within a selected chamber junction crossover (21) coinciding with the depth of the selected gravity-separated product.

(45) As depicted in FIG. 2, conventional solution mining configurations are not capable of performing a subterranean manifold function of selective control of simultaneously flowing fluid streams, as an innermost leaching string (2) freely hangs within an outer leaching string (2A) without a crossover radial passageway or the ability to selectively direct and/or re-direct flow streams. Simultaneous flow streams for the conventional configuration shown consist of injecting (31) water and extracting (34) brine, wherein the injection (31) or extraction (34) may occur through the innermost string (2) passageway (25) with contrary flow orientations within the concentric passageway (24), or vice versa. A leaching cushion or blanket of hydrocarbons or inert gases, such as nitrogen or diesel, is generally communicated through the first annular passageway (55) to control salt dissolution axially upward.

(46) In conventional applications, simultaneously flowing streams within the subterranean cavern space, that is being solution mined using a salt dissolution process, are restricted to injection (31) of a salt inert cushion fluid and water with production (34) of salt saturated brine from, and into, the innermost passageway (25) and concentric passageway (24, 54). Flow into the innermost passageway (25) from the concentric passageway (24), and vice versa, is not possible without first passing through the first annular passageway (55).

(47) Conventional practice does not provide communication between concentric passageways (24, 25) without first entering the first annular passageway, and only innermost string (2) depth may be adjusted with a large hoisting capacity rig being required to remove and rearrange both conduit strings (2, 2A) to affect water exit and brine entry depths. Conversely, a manifold string member (70N) embodiment, having one or more manifold crossovers (for example 21 of FIGS. 117-122), can be usable to selectively control simultaneously flowing fluid streams, between the innermost and concentric passageways, by placing straddles and plugs to isolate and divert fluid through one or more radial passageways without cutting or removing conduit strings with a large hoisting capacity rig.

(48) After solution mining the well, a completion (2, 40, 74 and 10 of FIG. 1) can be installed to form an underground storage well through the final cemented casing (3), once the dual string (2 and 2A) arrangement used to enlarge the space within the cavern walls (dashed lines 1A of FIGS. 1 and 2) using a salt dissolution process, is removed. This salt dissolution process includes the use of a leaching valve tree (10A) to inject (31) water for producing (34) a substantially water brine, that comprises liquid water and solid salt dissolved within a fluid mixture (38), to enlarge the space within the cavern walls (1A), formed in the salt deposits (5) that are disposed within the subterranean regions. A member embodiment manifold string (70N) with free hanging conduit string members (2, 2A), that are engaged with chamber junction crossovers (21) can be usable to prevent the need to remove the outer leaching string for adjustment of solution mining operations. A valve tree (10A) with associated wellhead (7), that can support concentric conduit string members (2, 2A), together with a chamber junction manifold crossover (21), can be usable to access different specific gravity products stored in a cavern and naturally separated by gravity where the manifold string (70P of FIG. 1) with a production packer (40 of FIG. 1) and subsurface valve (74 of FIG. 1) replaces the conventional solution mining configuration or manifold string (70N).

(49) Referring now to FIG. 3, a conventional wireline rig (4A) is shown, that can be usable to selectively place flow controlling members, for reconfiguring a manifold string member arrangement, or to physically reconfigure a manifold string member using rotary cable tools. The rotary cable tools can be conveyed, for example, through a valve tree (10) and wellhead (7) for placement within the innermost passageway or innermost passageway connector of a manifold string. In addition, FIG. 3 shows closable surface valves (64) engagable to a blow out preventer (9) and lubricator (8), that can be separated to place flow controlling members within the lubricator. Then, the valves can be opened while a wire or cable (11), that is passing through a pressure containing stuffing box or grease injector head at the upper end of the lubricator provides pressure containment, with flow controlling apparatuses lowered or hoisted (12) with a winching apparatus for placement within the passageways through subterranean strata (52 of FIGS. 1-2).

(50) Any form of rig (4), comprising, for example, a coiled tubing unit or drilling rig, using continuous or jointed conduit-in-conduit operations, are usable to convey flow-controlling members within a manifold string. During well construction, when, for example, a managed pressure conduit assembly (49 of FIGS. 100-105) functions as a manifold string member, placed through a drilling rig blow out preventer, that can be used to control the first annular passageway (55 of FIGS. 1-2), until the manifold string may be engaged to the wellhead (7), for controlling the annular passageways (24, 24A of FIGS. 1-2), with a surface valve (64) tree installed later for controlling inner passageways and engagement with a slickline rig (4A). A fluid mixture, referred to as drilling mud, can pass through a drilling rig riser to a bell nipple where circulated drilling mud returns after passing through the string and drilling rig blow out preventer. A drilling rig diverter may perform a similar fluid control function as a stuff box, should the drilling mud fail to contain subterranean pressures. Similar to the wireline rig (4A), a drilling rig (4) can be usable to place a manifold string or flow controlling device by using a drawworks to hoist (12) a cable (11), passing through the crown block of a derrick for placement within the passageway through subterranean strata (52). The manifold string can be used to selectively control a fluid mixture of drilling mud, cement and proppant fracture liquids and solids or other construction fluid mixtures, that are simultaneously flowing through an innermost passageway and concentric passageway.

(51) Embodiments of the present invention provide at least one direct crossover through a radial passageway, between the innermost passageway (25) and one of concentric passageways (24, 24A, 54), with or without first passing through an adjacent concentric passageway (24, 24A, 54) or the first annular passageway (55), wherein a flow controlling member selectively affects fluid communication through the radial passageway using, for example, a valve tree (10A) or standpipe manifold to affect fluid velocity and associated pressure within one or more of the passageways (24, 25). This selective control of the velocities and associated pressures within the passageways can be used to, for example, construct a well and/or provide production simulation similar to a velocity string or subterranean processing, for the purpose of separating hydrocarbon gas so that such gas may be used to gas lift one or more the remaining passageways of a substantially liquid flow stream at selected depths and pressures, thus further enhancing production.

(52) FIG. 4, shows a chart depicting exemplary relationships present within a prior art velocity string, explanatory of a flowing bottom hole pressure versus a flow rate method function chart for hydrocarbon flow. The bottom hole pressure increases upward along the vertical axis of the chart, and flow rate increases to the right along the horizontal axis of the chart. Over the life of a hydrocarbon reservoir, the pressure function (F1, F2, F3) of flow rate versus flowing bottom-hole pressure decreases from F1 to F3 as the reservoir pressure depletes. The diameter of a production string (2 of FIG. 1) affects the velocity and the associated frictional resistance and pressure, determining where the minimum unaided flow rate (P1, P4) occurs, which can be compared to the critical flow rate (P2, P3), that is associated with the bubble point of gas within the hydrocarbon fluid mixture, described by functions F4 and F5.

(53) When a well is initially constructed, the economic decision between installation of a larger diameter string (F5) and a smaller diameter velocity string (F4) must be made by comparing the initial flow rate (FR1) and final flow rate (FR3) of the larger diameter string to the lower initial flow rate (F2) and higher final flow rate (F4) of the velocity string, relative to reservoir pressure depletion and natural flow.

(54) As the economics of replacing the larger diameter production string (F5) with a smaller diameter production string (F4) for a depleted reservoir are often unfavourable, the lower flow rates of the larger string (FR3) may be accepted over the higher potential flow rates (FR4) of a velocity string.

(55) Manifold string members usable within the scope of the present disclosure can provide a means to follow the flow rates from FR1 to FR2 with a large diameter string, followed by wireline rig (4A of FIG. 3) intervention to selectively place flow controlling members to adjust the effective diameter of the producing string at the flow rate FR5, by diverting all or a portion of production through one or more manifold crossovers. Through repeated wireline intervention, the velocity string function between F5 and F4 may be followed to produce hydrocarbons at a higher rate without the need to remove the producing string.

(56) Referring now to FIG. 5, an example of a hydrocarbon liquid, gas phase explanatory pressure versus temperature functional chart is shown. The chart shows pressure increasing upward along the vertical axis and temperature increasing to the right along the horizontal axis. The chart of FIG. 5 includes a bubble point curve 1 function of a more liquid fluid mixture (F6) and a bubble point curve 2 for a more gaseous fluid mixture (F7) intersecting a vertical line of constant temperature at point C. The bubble point curve 1 function (F6) shows that outside the bubble curve envelope, above the critical point, an all liquid fluid mixture exists and below the critical point, outside the bubble curve envelope, an all gas fluid mixture exists. However, within the bubble curve a liquid and gas fluid mixture exists. Functions F8, F9 and F10 show 25 percent, 50 percent and 75 percent liquid fluid mixtures, respectively.

(57) During production, as pressure exerted on the reservoir is decreased from A1 to A2 by opening the valve (64 of FIG. 1) of a surface valve tree (10 of FIG. 1), the all liquid subterranean hydrocarbon fluid mixture transitions from liquid to a mixture of liquid and gas at point A2. If it was possible to maintain temperature during extraction through the cooler subterranean strata above a reservoir, the percentage of liquid would decrease to 75% at point B on function F10.

(58) When hydrocarbons are passed through a surface separator the fluid mixture may, for example, separate to 75% liquid at point S2 pressure and temperature. If the temperature drop, as a result of production, can be minimized to point S1 of a higher pressure, using the process of subterranean separation that uses the heat of the subterranean strata, a higher flow rate can achieved for the same 75% liquid fluid mixture. For the more gaseous fluid mixture function bubble point curve 2, the increase in pressure from S4 to S3 is more pronounced, thus, resulting in relatively higher flow rates when subterranean fluid separation is used to retain temperature.

(59) As described, since the produced flow rate is not only a function of pressure and temperature, but also reservoir depletion and the diameter of the producing string, the ability of the present embodiments to more selectively control flowing velocities, pressures and temperatures within the manifold string is usable to better manage flow rates over the life of a well, and includes better control of thermal factors affecting flow assurance when performing subterranean fluid processing.

(60) Additionally, a manifold string member, usable to provide subterranean separation, can also be usable to control simultaneously flowing fluid streams by gas lifting a substantially liquid flow stream with a selectively controlled and substantially gaseous flow stream, using gas lift valves between the two flow streams to further aid production using subterranean processing.

(61) In FIG. 5A, an example of a prior art hydrocarbon sandface pressure versus mass rate function chart is shown. The Figure shows increasing pressure upward on the vertical axis and increasing mass rate to the right on the horizontal axis. F11 represents the bubble point function with function F12, extending from point P5, representing the decrease in pressure exerted on the sandface of a reservoir by opening a valve tree and flowing at rate measured by the mass of the flowing mixture.

(62) The flowing function F13 represents a theoretical example of hydrocarbon capable of stable flow at pressure and flow rate point P6, which becomes unstable at the pressure and flow rate point P7. Thereafter, the Figure shows that stable flow cannot be achieved until reaching pressure and flow rate point P8.

(63) As is often found in practice, the pressure exerted at the sandface of a reservoir, by the opening of a well, is critical to stable production flow and various flow rates may work better than others. Hence a practical ability to selectively change the flow configuration of a hydrocarbon production string over its life span has a value as flow velocities, pressures and temperatures change with reservoir depletion.

(64) Prior art production methods typically focus on combinations of apparatus for single flow streams and relatively static configurations for subterranean separation, ignoring the dynamic nature of a subterranean fluid mixture flow stream of varying velocities, pressures and temperatures over the life of a well, because safety and/or economic factors typically prevent changing a production string once it is installed.

(65) By using a set of combinable member components, embodiments of the present invention manifold string can be usable to selectively control flow streams over the life of a well with flow controlling members, that are placed between the conduits of concentric strings and/or through the innermost passageway, accounting for theoretical production or injection functions for substantially water or substantially hydrocarbon wells, such as those described in FIGS. 4 and 5. Further, embodiments including manifold strings usable with flow controlling devices placed between the conduits of the concentric strings and/or through the innermost passageway, provide practicing artisans accessibility, through the innermost passageway, to place and/or remove further flow controlling members, that can selectively control the reality of a non-linear production function, like that described in FIG. 5A, over the life of a well, without incurring the same safety or economic impacts associated with replacement of a production string.

(66) Referring now to FIGS. 6-7, 8-16, 17-20, 21 and 22-37, manifold string and crossover members usable for changing the effective diameter and, thus, the velocity for a given flow rate over the length of a manifold string is shown.

(67) Manifold string members with, for example, the concentric conduit crossovers (23) of FIGS. 8-16 are engagable in series or in parallel above or below other manifold crossovers (23) of FIGS. 17-20. This engagement can be used separately or in combination with, for example, an adapted chamber junction (43) of FIG. 21, wherein various flow controlling members (61) of FIGS. 22-37 can be engagable with one or more receptacles (45), and can be further combinable with other members of a manifold string member set in any combination or arrangement with matching passageway members, to selectively control a plurality of simultaneously flowing substantially hydrocarbon and/or substantially water fluid-mixture flow streams.

(68) FIGS. 6 and 7 depict elevation cross-section and process diagrammatic views, respectively, of a member (70A) embodiment of a manifold string (70), usable as a selectively variable length velocity string. The Figure illustrates the inner concentric string (2) and outer concentric string (2A) engaged to a wellhead (7) and valve tree (10). A series of manifold crossovers (23, 23A, 23B of FIGS. 8-9, 23C of FIG. 10, and 23Y of FIG. 14) are usable to reduce the effective diameter forming a velocity string, as described in FIG. 4, by diverting at least a portion of a flowing fluid mixture, that is flowing into (32, 35) the innermost passageway (25) or into (33, 37) the adjacent concentric passageway (24), to effect the frictional equivalent of a velocity diameter along the length of a flow stream, by selectively placing flow controlling members. The upper most manifold crossover (23A) can remove the concentric passageway member (24) from use to allow valve (74) to control production. FIG. 7 shows a valve (74), such as a safety valve, operating with a control line (79) and a valve tree (10), to provide selective control of pressures in the well for controlled production from the well.

(69) The velocity string manifold crossover (23A) can be formed from the manifold crossover of FIGS. 8-9, wherein a portion of the concentric annular passageway (24) is permanently blocked to divert the entire fluid mixture stream (38) into the innermost passageway (25). Alternatively, the equivalent of a manifold crossover member (23A) can be formed by covering only the orifices (59 of FIG. 13) below the receptacle (45 of FIG. 13) in the manifold crossover member (23C of FIG. 13).

(70) Referring now to FIG. 8, a plan view with line A-A, associated with FIG. 9, of an embodiment (23B) of a manifold crossover member (23), wherein all of the innermost passageway (25) flow stream may be diverted through the radial passageway (75 of FIG. 9) to the concentric passageway member (24), if a blocking device is placed in the receptacle (45 of FIG. 9). However, only a portion of the concentric passageway (24) flow can be commingled with the innermost passageway, as through passageways are provided. These through passageway members are permanently blocked in the FIGS. 6-7 manifold crossover (23A).

(71) A manifold crossover member (23B) of this configuration is usable, in a potentially inverted orientation to that shown in FIG. 9, at the lower end of a hydrocarbon fluid separation member space, for allowing heavier fluids to travel to the passageway member of least frictional resistance and larger effective diameter, while lighter and more gaseous fluid streams are more able to expand and travel through the higher frictional passageway member, forming two separate simultaneously flowing fluid mixture streams of varying velocities.

(72) In FIG. 9, an elevation cross-section view along line A-A, showing the manifold crossover (23B) member of FIG. 8 is depicted. The Figure illustrates, portions of the concentric passageway (24) that are blocked by the wall (75A, shown in FIGS. 8 and 9) of the radial passageway (75), in fluid communication between the innermost passageway (25) and the concentric passageway (24), which is between the innermost string (2) and adjacent concentric string (2A) with ends (90) engagable to other conduits of a manifold string members. The crossover may be oriented as shown or rotated, wherein the radial passageway slopes downward and inward instead of upward and inward.

(73) Fluid mixtures may be injected (31) or produced (34) through any passageway (24, 25), dependent on the engaged flow controlling member. If, for example, a straddle (22 of FIG. 93A) is engaged to the receptacle (45) to block the radial passageway (75) orifices (59), unidirectional or axially opposing flow orientations between passageway member flow streams can be usable to operate a well. If a choke controls the orifices (59) of the radial passageway (75) to commingle only a portion of a flow stream (32, 33) through either passageway (24, 25), then other various flow arrangements, including for example separation and/or gas lift, can be facilitated selectively by installing a plurality of manifold crossovers (23B), then selectively placing straddles and chokes to define flow of the fluid mixture stream configurations.

(74) The manifold crossover (23B) is similar to the orifice manifold crossover (23) member at the lower end of the chamber junction crossover (21) of FIGS. 117 and 119-122, wherein the radial passageway wall (75A) is more suited for higher erosional velocities.

(75) Referring now to FIGS. 10 and 12, plan views with lines B-B and C-C associated with FIGS. 11 and 13, respectively, of an embodiment (23C) of a manifold crossover member (23) are shown. The Figures illustrate a section line (B-B) through the concentric passageway (24) and another section line (C-C) through the radial passageway (75) wall (75A), contained between an inner concentric conduit (2) and outer concentric conduit (2A).

(76) FIGS. 11 and 13, depict elevation cross-section views along lines B-B and C-C of FIGS. 10 and 12, respectively, showing a manifold crossover (23C). The Figures illustrate an embodiment where two flow streams can be separated, crossed-over or commingled, dependent upon the flow controlling member engaged to the receptacle (45). The injection (31) or extraction (34) of a fluid mixture may occur through either the innermost passageway (25) or the adjacent concentric passageway (24), between conduits (2, 2A) with ends (90) engagable to other conduits of manifold string members, wherein flow streams above and/or below the receptacle (45) may be crossed over through the radial passageway (75). Various flow arrangements, using various flow controlling members engaged within this manifold crossover (23C), are shown in FIGS. 22-29.

(77) An exemplary arrangement of an engaged flow controlling member includes using a straddle to block the orifices (59) above or below the receptacle (45) for blocking the concentric passageway (24) below or above the receptacle (45), respectively, while commingling the contrary concentric passageway (24) with the innermost passageway (25). Other examples of arrangements of engaged flow controlling members includes blocking orifices (59), both above and below the receptacle (45), with a straddle to block the concentric passageway (24) while allowing the innermost passageway (25) flow stream to flow through the bore of the straddle, or by placing a blocking flow controlling member, engaged to the receptacle (45) within the innermost passageway, to cross over flow streams between the innermost (25) and concentric (24) passageway members, as described in FIGS. 22-25.

(78) The manifold crossover (23C), of FIGS. 10-13, compliments the chamber junction crossover (21) member, of FIGS. 117 and 119-122, by providing the ability to block all or to divert part of a flow stream that can be communicated through the concentric passageway (24). The chamber junction crossover (21 of FIGS. 117 and 119-122) can only divert to the concentric passageway. Combining these two manifold crossover members (21 and 23C) in series provides the ability to selectively block both the innermost (25) and concentric (24) passageways or to divert one to the other.

(79) The manifold crossover (23C) of FIGS. 10-13 also compliments the manifold crossover (23Y) of FIGS. 14-16, engaged axially above or axially below the depicted manifold crossover (23C) providing the ability to block all or to divert part of a flow stream communicated through the concentric passageway (24) to the innermost passageway (25). The manifold crossover (23Y of FIGS. 14-16) can be usable to block all or to divert part of a flow stream, communicated through the concentric passageway (24) to a different concentric passageway (24A) and/or the innermost passageway (25). Combining these two manifold crossover members (23C and 23Y) in series, with an additional conduit string member (2B) placed about 23C, provides the ability to selectively block or divert a plurality of concentric passageway members (24, 24A of FIG. 14).

(80) Referring now to FIGS. 14 and 15, isometric and magnified views are shown with detail line D and within detail line D, respectively, and dashed lines show hidden surfaces in FIG. 15, of a manifold crossover member (23) or slurry passageway (58) embodiment (23Y) that can be associated with FIG. 16. The embodiments depicted in the Figures show a crossover similar to that of FIGS. 11 to 13, with a dashed line representing an additional concentric conduit (2B or 51) or the passageway through subterranean strata (52), with an additional concentric conduit passageway (24A) if the additional conduit (2B or 51) is present, or with the first annular passageway (55) if the additional conduit (2B, 51) represented by the dashed line is not present.

(81) Radial passageway (75) orifice (59) members can be located within the innermost passageway (25, 53), formed by the inner conduit string (2, 50). The members can be arranged similar to the manifold crossover (23C) of FIGS. 10-13, except an additional wall (82) can be placed within every other radial passageway (75) wall (75A), with an associated orifice (59A) of the concentric conduit (2A). Every other radial passageway can fluidly communicate between the concentric passageway (24, 54) or the additional concentric passageway (24A, 55) and the innermost passageway (25, 53). The arrangement of radial passageways (75) between passageway members (24, 24A, 25, 53, 54, 55) and the innermost passageway (25, 53) is similar to the chamber junction (21) manifold crossovers of FIGS. 117 and 119-122 or a slurry passageway apparatus (58), in that a radial passageway (75) passes through an adjacent concentric passageway (24, 54) to connect the innermost passageway (25, 53) directly to a non-adjacent concentric passageway (24A, 55).

(82) FIG. 16 depicts an isometric view associated with the manifold crossover (23Y) of FIGS. 11 to 15. The Figure illustrates the apparatus without the outer concentric strings (2A, 2B of FIG. 15) to show the arrangement of radial passageways, where every other passageway communicates between the innermost passageway (25, 53) and the adjacent passageway (24, 54 of FIGS. 14-15). The remaining radial passageways (75) can be diverted, by an additional wall (82) to an orifice (59A of FIGS. 14-15) in the adjacent outer wall (2A of FIGS. 14-15), to form a direct passageway between the innermost passageway (25, 53) and the first annular passageway (55 of FIGS. 14-15), or an additional concentric passageway (24A, 54 of FIGS. 14-15) with the outer wall of the receptacle (45) protruding into, but not blocking, the concentric passageway (24, 54 of FIGS. 14-15).

(83) Referring now to FIGS. 17, 18 and 19: plan, elevation and isometric views, respectively, associated with FIG. 75, are shown, with dashed lines depicting hidden surfaces of an embodiment (23D) of a manifold crossover member (23). The manifold crossover member can be usable with the adapted chamber junction of FIGS. 20 and 21. The Figures show the innermost passageway connectors (26), engagable between, for example, exit bore conduits (39 of FIGS. 20-21) and conduits continuing the innermost passageway (25 of FIGS. 20-21) of each exit bore conduit. The Figures include two radial passageways (75), between the left innermost passageway connector (26), which can fluidly communicate with two orifices (59) of the manifold crossover (23D), engagable to the orifices (59B of FIG. 20) of the concentric passageway (24 of FIG. 20) located between the inner concentric conduit (2 of FIG. 20) and an outer concentric conduit (2A of FIG. 20). An example of an analogous arrangement is shown in FIG. 82.

(84) Straddles may be placed across one or both of the radial passageways (75) to prevent radial flow. Alternatively, a plug may be placed within the left innermost passageway connector (26) to urge radial passageway flow. The orifices (59) can be engaged to the same concentric passageway (24 or 24A of FIGS. 15 and 20) or to different concentric passageways (24 and 24A of FIGS. 15 and 20) to allow simultaneous flow into (32, 35) the innermost passageway members (26 and 25 of FIGS. 19-21) or into (33, 37) a concentric passageway (24, 24A of FIGS. 15 and 20), for injection or production through either the innermost passageways or the concentric passageways.

(85) FIGS. 20 and 21 depict plan and isometric views of an adapted chamber junction (43), usable to form a manifold crossover member (23) when combined, for example, with the manifold crossover (23D) of FIGS. 17 to 19. The Figures depict an inner concentric string member (2) within an outer concentric string member (2A), forming a chamber wall (41) and additional single main bore conduit (78) with orifices (59B) in the chamber junction bottom (42), for fluid communication of the concentric passageway (24). Other concentric conduits (2B shown as a dashed line) and other orifices (59C) can be added to fluidly communicate with one or more orifices (for example 59 of FIGS. 17-19) or concentric string members (for example 2, 2A and 2B of FIGS. 14 and 15) of a manifold crossover (23).

(86) Referring now to FIGS. 22 and 24, plan views with lines B-B and C-C associated with FIGS. 23 and 25, respectively, of a manifold string member (70) embodiment (70J) are shown. The Figures depict the manifold string member (70) embodiment (70J) with a manifold crossover (23C of FIG. 10-13 or 23Y of FIGS. 14-16) and a flow controlling member (61), shown, for example, as a blocking plug (25A) installed within a receptacle (45 of FIGS. 23 and 25). The Figures illustrate the inner concentric string (2 of FIGS. 23 and 25) and outer concentric string (2A of FIGS. 23 and 25) forming a concentric passageway (24), that can be diverted by radial passageway walls (75A) to orifices in the innermost passageway member (25 of FIGS. 23 and 25).

(87) FIGS. 23 and 25 depict elevation cross-section views along lines B-B and C-C of FIGS. 22 and 24, respectively. The Figures show a manifold string (70J), with a blocking or plug (25A) flow controlling member (61) engaged to a receptacle (45) via mandrels connectors (89) located within the manifold crossover (23C) of FIGS. 22 and 24. The ends (90) of the manifold string (70J) are engagable with other manifold string members. The plug (25A) can be placed through the innermost passageway (25) with a wireline rig (4A of FIG. 3) cable (11 of FIG. 3) and engaged to a connector (68) for hoisting (12 of FIG. 3) into, or out of, the passageway through subterranean strata (52 of FIGS. 1 and 2). After placing or removing the plug (25A), the cable engagement with the connector (68) may be disengaged.

(88) The innermost passageway (25) of the inner concentric string (2) can be blocked by the plug (25A), forcing injection (31) or production (34) to cross from the innermost passageway (25) to (33) the concentric passageway (24) or from the adjacent concentric passageway to (32) the innermost passageway through the radial passageways (75).

(89) Crossing over flow streams, between the innermost passageway and a concentric passageway, can be usable to, for example, form the preferred manifold crossover valve embodiment (23F) of FIGS. 42 and 44-45. In this embodiment, a subterranean valve (74 of FIGS. 42 and 44-45) can be placed on either end of the manifold crossover (23C) with a plug (25A) installed to provide selective control of each flow stream with the subterranean valves, while providing access through the innermost passageway (25) when the plug is removed. The subterranean valve can be controlled, independently, in applications were separate selective control is required or controlled together if, for example, the subterranean valve is a subsurface safety valve intended to fail safe shut.

(90) Alternatively, the crossover over of flow streams with a flow controlling member (61) comprising, for example, a choke or a pressure-controlled valve or one way valve installed within the receptacle (45) instead of the plug (25A), can provide a space within the passageways for varying the velocity of flow streams and the associated pressures at varying subterranean depths. The temperature of the strata can be factored in when selectively reconfiguring a subterranean processing space to, for example, separate fluids and/or gas lift a substantially liquid flow stream by allowing a portion of a crossed over gas stream under the flow controlling member to enter a substantially liquid crossed-over flow stream, without the need to use conventional side pocket mandrels and gas lift valves that, in practice, are often more difficult to access than a valve placed in a nipple profile receptacle, across the innermost passageway member.

(91) Alternatively, if the manifold string (70J) is adapted with the crossover (23Y) of FIGS. 14-16 is used instead of the manifold crossover (23C) shown in FIGS. 22-25, flow can be selectively directed into (35) the innermost passageway (25) from a non-adjacent concentric passageway (24A or 55 of FIGS. 14 and 16), or selectively directed into (37) a non-adjacent concentric passageway (24A or 55 of FIGS. 14 and 16) through the innermost passageway (25).

(92) Referring now to FIGS. 26 to 39, apparatuses for performing rotary operations usable with other rotary cable apparatuses and methods within conduits of a manifold string (70 and 76 of FIG. 51) member over the life of a subterranean well, are shown. The Figures include a cable (11 of FIG. 3) engagable downhole motor and/or pump assembly (69) flow control device (61), that can be placeable, suspendable and retrievable via a cable hoisted with a wireline rig (4A of FIG. 3). The Figures further include an electric motor (111) or fluid motor, using, for example turbines, impellors or rotors and stators, with fluid inlets and outlets (59) associated with a radial passageway (75) located within a manifold crossover (23) for directing a first fluid mixture flow stream to act upon a fluid motor, that can be operable with differential fluid pressure or velocity of expanding or compressed gases for pumping a second fluid mixture flow stream.

(93) As energy within any system is conserved, being neither created nor destroyed, using a manifold string to selectively place flow controlling apparatus within separate flow streams of varying velocity, can be usable to provide artisans of the art with a means to control how energy is distributed from a first simultaneously flowing fluid mixture stream to the second to, in use, better allocate available energy within the system.

(94) Referring now to FIGS. 26 and 28, plan views with lines B-B and C-C associated with FIGS. 27 and 29, respectively, are depicted and show an embodiment (70K) of a manifold string member (70) with a manifold crossover (23C of FIGS. 10-13, 23Y of FIGS. 14-16) and concentric conduits (2, 2A) about an embodiment (69A) of a fluid motor and fluid pump (69 of FIGS. 27 and 29) flow controlling member (61 of FIGS. 27 and 29). The Figures illustrate an arrangement, usable to pump a fluid through a passageway, using the velocity and pressure of flowing fluids or gas expansion of a first flow stream to pump a second flow stream.

(95) FIGS. 27 and 29 depict elevation cross-section views along lines B-B and C-C of FIGS. 26 and 28, respectively. The Figures show the manifold string (70K) arrangement with a motor and a fluid pump (69A) flow controlling member (61), that is engaged to a receptacle (45) with an engaging connection (89) to the manifold crossover (23C or 23Y). The Figure illustrates the inner concentric string (2) and outer concentric string (2A) forming the concentric passageway (24) and innermost passageway (25), usable to place and operate the flow controlling member (61), using the engagement (68) and a wireline rig (4A of FIG. 3) for placement. The ends (90) of the manifold string member can be engagable with other conduit members of the manifold string (70) arrangement to flow a first simultaneously flowing fluid mixture, which can be used for operating the fluid motor to pump a second simultaneously flowing fluid mixture of varying velocity.

(96) Internal components of the fluid motor and fluid pump (69) are similar to that shown in FIGS. 36-37, with a shaft connecting two fluid rotatable devices (112), for example a turbine or an impellor that can be configured to be operated with the fluid and to pump the fluid from two separate simultaneously flowing fluid mixtures. For example, fluid injected (31) into (32 and 35) the innermost passageway (25), through a radial passageway (75) from a concentric passageway (24 and 24A of FIGS. 14-15, respectively) below the crossover (23C, 23Y), can operate a rotatable turbine (112) that is engaged with a shaft connected to another turbine (112), which can be usable to pump produced (34) fluid into (32 and 35) the innermost passageway (25), through a radial passageway (75), from a concentric passageway (24 and 24A of FIGS. 14-15, respectively) above the crossover (23C, 23Y). As an alternative example, fluid produced (34) through member passageways by natural expansion and/or subterranean pressure of a stored compressed gas or by gas entrained fluid to (33, 37) a concentric passageway (24A, 24) that flows through a radial passageway (75) from the innermost passageway (25) below the crossover (23C, 23Y), can operate the rotatable turbine (112). The rotatable turbine (112) can turn an engaged shaft connected to another turbine (112) and can be usable to pump, for example, a substantially liquid produced (34) fluid from a subterranean separation process or, for example, a substantially water fluid mixture injected (31) into a proximal region of the passageway through subterranean strata. The substantially water fluid can be used for solution mining or disposal between the innermost passageway (25) and a concentric passageway (24, 24A) through the radial passageway members (75).

(97) Referring now to FIG. 30, a plan view with line F-F associated with FIG. 31 and detail line G associated with FIG. 35 is shown. The Figure depicts a manifold string embodiment (70G) with an embodiment (69B) of a motor and a fluid pump (69 of FIG. 31) flow controlling member (61 of FIG. 35) placed within a manifold crossover member (23) embodiment (23E of FIG. 31).

(98) FIGS. 31 and 34 depict elevation cross-section and isometric views, respectively, along line F-F of FIG. 30. The detail lines H and I of FIG. 31 are associated with FIGS. 32 and 33, respectively, and the break line of FIG. 31 is associated with FIG. 34. FIG. 34 depicts an axial cross-section representing a portion of concentric conduits that are removed from a manifold string (70G), potentially extending to an engagement with a wellhead and/or valve tree at the upper ends (90) as shown in FIG. 31. FIGS. 31 and 34 show a motor and fluid pump (69B), placeable with the cable connector (68) and engaged within the manifold crossover (23E) receptacle (45 of FIG. 32) with engagement apparatus (89 of FIG. 32). The inner concentric string (2) and outer concentric string (2A) lower ends (90) are shown as engagable to other conduits within the passageway through subterranean strata (52 of FIGS. 42 and 44) to vertically separate subterranean proximal regions. This separation of the subterranean regions can be accomplished by using, for example a chamber junction crossover (21 of FIGS. 117 and 119-122) and/or laterally separated regions, using, for example, the chamber junction manifold crossover (23T of FIGS. 83-87) access through exit bore conduits (39 of FIGS. 83-87). This separation can be used when, for various reasons, it is desirable to keep simultaneously flowing fluid streams within the same passageway member, above and below the manifold crossover member (23E).

(99) Within the manifold crossover (23E) embodiment, fluid mixtures of liquids, gases and/or solids may be injected (31) or produced (34) through member passageways (24, 25), wherein fluid is communicated through radial passageways (75) and orifices (59) out of a passageway (24, 25) to operate any rotatable device (112), and returning the flow stream to the originating innermost and concentric passageway members. Rotatable devices (112) are shown, for example, as a fluid motor and a fluid pump member (69B).

(100) Referring now to FIG. 32, a magnified view of the portion of the motor and fluid pump (69B) receptacle engagement (45 and 89), within detail line H of FIG. 31, is shown. The Figure shows injection (31) and production (34) travelling through the radial passageway (75). Sealing (66) flow controlling members (61) are provided to contain the pressure of one fluid mixture stream from commingling with another.

(101) FIG. 33 depicts a magnified view of the manifold crossover (23E). The Figure illustrates an innermost passageway, blocking, rotatable, shaft engagement member portion of the motor and fluid pump (69B) within detail line I of FIG. 31. The Figure includes a rotary connector (72) engaged in a receptacle (45A) member that is blocking (25A) the innermost passageway (25) to which a turbine (112) shaft (113 of FIG. 37) is engaged, and wherein injected (31) or extracted (34) fluid mixture, flowing within the innermost passageway, engages and operates the rotatable turbine (112), or is pumpable by the turbine, if the fluid mixture passing the associated turbine at the other end of the shaft drives the assembly. Sealing members (66 and 66 of FIG. 32) control the flow, within the innermost passageway, of the fluid mixture flowing (31, 34) above and below the plug (25A) and entering orifices (59) for flowing to the radial passageway (75) members on the right and left, to the engaging turbines (112 and 112 of FIG. 31) at opposite ends of the shaft, within the innermost passageway (25).

(102) Other manifold string (70G of FIG. 30) conduit string members are engagable to the ends (90), wherein a plurality of concentric conduits (2, 2A) or a single conduit (2) can be usable with a concentric conduit passageway or the first annular passageway, respectively, below the manifold crossover (23E).

(103) FIG. 35 depicts a magnified view of the portion of the manifold string (70G) motor and fluid pump arrangement (69B) within detail line G of FIG. 30. Dashed lines, showing hidden surfaces, illustrate the inner concentric string (2) and outer concentric siring (2A) between which, the flow-controlling member (61) manifold crossover (23E) alternating upper and lower orifices (59), leading to radial passageways (75), urge injection (31) and/or production (34) through the manifold crossover (23E). The flow through the manifold crossover can be used for operating a flow controlling member (61), shown in the Figure, for example, to be a fluid motor and fluid pump (69B) operated by simultaneously flowing fluid streams of various velocities and/or associated pressures.

(104) Referring now to FIGS. 36 and 37, plan and elevation cross-section views with line J-J and along line J-J, respectively, of a flow controlling device (61), are depicted. The flow controlling device is shown comprising a motor and fluid pump (69) embodiment (69B), showing a rotatable fluid operable apparatus (112) engaged with a shaft to the apparatus (112), which can be usable to pump a fluid, shown for example, as a fluid turbine arranged to drive and be driven at the ends of a shaft (113) within a housing (114) by passing fluid. The Figures include connectors (89), engagable to associated receptacles (45 of FIG. 32), for anchoring the member flow controlling apparatus (61). In addition, blocking (25A) and/or sealing (66) apparatus members can be usable for controlling fluid within and between the innermost passageway and concentric passageway through the radial passageway members.

(105) Any form of engagement or fluid operable components, for example a rotary connector (72) with seals (66) or bearings, races, slidable engagement components or mechanical features, such as a planetary gearing arrangements for differing upper and lower turbine or impeller rotational speeds, that is usable in a subterranean environment to operate the fluid operable motor or pump, can be usable with the present invention. The apparatus can be selectively placeable within a manifold string receptacle (45 of FIG. 32, 45A of FIG. 33), using a cable connector (68) and cable rig (4A of FIG. 3) or conduit connector and coiled tubing or drilling rig. Alternatively, the apparatus can be selectively placeable between conduits of conduit string members with such devices as a drawworks, during conventional installation. Other operable component alternatives, for example, can be formed when the innermost passageway member is fluidly communicated through the shaft with various other flow streams that can be communicated through various other concentric passageways and/or the first annular passageways, usable to operate the fluid motor and pump.

(106) FIGS. 38 and 39 depict elevation cross-section views of alternative motor and pump arrangements for various motor and fluid pump (69) embodiments (69C, 69D, respectively). The Figures depict: a rotor (109) and stator (108) arrangement (69C), that can be operable with injection (31) or production (34) and usable to rotate a fluid pump comprising, for example, a turbine or a positive displacement rotor (109) and stator (108) pump, as shown in FIG. 38. FIG. 39 shows an electric motor (111) arrangement (69D), that can be usable with an electrical cable (110A) and fixed or sealed (66) wet connections (110), to operate any downhole fluid pump for producing (34) or injecting fluid, if the orientation is inverted. Fluid to either arrangement can be supplied by a manifold crossover through a radial passageway of a manifold string member.

(107) As demonstrated in FIGS. 6 to 39, and later described in FIGS. 69-75 and 83-87, preferred manifold crossover (23) embodiments of the present invention provide systems and methods combinable in any configuration or orientation to selectively control separate flowing fluid streams of injection (31) and/or production (34) fluid mixtures (38) of liquid, gases and/or solids. This selective control can be achieved at varying velocities and associated pressures, selectively communicated through radial passageways (75) and orifices (59), either directly (32) or indirectly (35) into the innermost passageway members (25, 26) from another concentric passageway (24, 24A, 24B, 25, 26, 54, 55) member, and/or directly (33) or indirectly (37) into a concentric passageway (24, 24A, 24B, 55) member from the innermost passageways (25, 26) or other concentric passageways (24, 24A, 24B, 55) with selectively placed flow controlling members (61 of FIGS. 1-123) and/or flow controlling member embodiments (69A, 69B, 69C, 69D). The flow controlling members can be engaged between the conduits of an inner concentric string (2) and/or outer concentric string (2A), or conveyed, placed and/or retrieved through the innermost passageways (25, 26) and engaged to a receptacle (45, 45A). The combined manifold string (70, 76) embodiments can be usable to operate one or more substantially hydrocarbon and/or substantially water wells, from a single main bore and wellhead.

(108) Referring now to FIGS. 40 and 41, elevation diagrammatic cross section views of prior art subterranean production and waste water disposal simultaneous flow stream application and a surface hydrocarbon fluid separation process, respectively, that together with wells described in FIGS. 1-2 and FIGS. 46-47 depict conventional processes improvable, combinable and/or replaceable with preferred embodiments of the present invention.

(109) FIG. 40 shows a valve tree (10) engaged to a wellhead (7) with an annulus valve (81) controlling injection (31) through an annular passageway, between the intermediate (15) and final cemented casing (3) and into a fracture (18) below the casing shoe (16), which prevents upward flow within the annulus space outside the intermediate casing. The Figure shows that pressure can propagate (28) to the point of fracture propagation (30), allowing waste fluids to be disposed of within a subterranean feature. Fractures (18) may be allowed to close with stoppage of injection (31). Waste solids may act as proppants, in a similar manner to the single stage shale gas fracture stimulation at the lower end of the production tubing (2), where proppants (generally sand sized particles), are injected to hold fractures open. This opening of the fractures can maintain, for example, fluid communication throughout the fractures (18) for gas production (34), from relatively impermeable shale formations otherwise incapable of significant production. Production flow (34) controlled by a subsurface valve (74), may occur at the same time as waste injection (31) into the upper fracture (18). Alternatively, dedicated conventional waste disposal well injection (31) can occur through the valve tree (10) controlled by a surface valve (64) and the tubing (2) to the lower fracture (18) point of propagation (30) for substantially water injection wells.

(110) FIG. 41 shows an above ground level (121) surface hydrocarbon separator (115) taking a fluid mixture (38) of liquids, gases and/or solids, which was produced (34) from the tubing conduit string (2) controlled by a subterranean valve (74), operated with a control line (79). A space of reduced pressure within the separator (115) allows a heavier specific gravity substantially water fluid stream to be pumped (116) to disposal processing. The lighter specific gravity substantially liquid hydrocarbon is shown floating (117) on the water flowing in an intermediate substantially liquid fluid flow stream (119) of hydrocarbons, with formerly compressed substantially lighter specific gravity gases expanding and exiting the upper fluid level (118), to be produced in an uppermost substantially gaseous fluid stream (120).

(111) FIGS. 1-2, 6-7, 42-46, 48-52, 67-68 depict elevation diagrammatic cross section views of manifold string members (70, 76), wherein single well manifold string (70) arrangements are usable, individually, or in combination below a junction of wells (51A of FIG. 50). The combined manifold strings can be used to form a plurality of wells manifold string (76) members, which can be usable for subterranean processing and/or providing a plurality of fluid streams, wherein the combinable members are usable to replace one or more convention wells and/or supplement or replace conventional processing arrangements, for example those described in FIGS. 1-2, 40-41 and 46-47.

(112) For the purposes of forming an off-the-shelf manifold string member set applicable to substantially hydrocarbon and/or substantially water wells and processing systems, members comprising, for example, conventional flow controlling members (61), that can be operable with other set members, can be usable for urging, measuring and/or selectively controlling fluid mixtures of liquid, gas and/or solids, for one or more substantially hydrocarbon wells, substantially water wells, or combinations thereof, such as combined solution mining and storage wells. Examples of such flow controlling members include: surface pumps (116), surface valves (64, 81), valve trees (10, 10A) and wellheads (7) that can be engagable to the upper end of a manifold string (70, 76) member and that are usable to control a single fluid mixture flow stream (31, 34) with a plurality of velocities and/or a plurality of fluid mixture flow streams (31, 34), with varying flow stream velocities. In addition, subterranean valves (63, 74, 84) can be used for controlling the flow of fluid mixtures in passageways (24, 24A, 25, 26, 55) members. Additional flow controlling members include downhole gauges, velocity switches, pressure activation mechanisms, acoustic or fluid-pulse signals for passing a fluid, control lines (79) and/or other selective measurement, activation and/or control means, including one way devices, surface or subterranean chokes (77), venturi (85), jet pumps (85), plugs (25A), casing shoes (16), packers (40), fracturing technologies, and/or, motor and fluid pumps (69).

(113) FIGS. 42 and 43 depict elevation cross-section and process control diagrammatic views, respectively, of an embodiments (70B, 70L, respectively) of subterranean flow-stream, separation, manifold string (70) members with a motor and fluid pump (69) flow controlling member (61), that can be used to pump separated liquids. The Figures show a manifold crossover embodiment (23F) flow controlling member (61) with a subsurface valve arrangement. The Figures include a fluid mixture (38), produced (34) through passageway members, that is separated into a plurality of simultaneous flowing fluid mixture streams controlled separately by a plurality of valves (74). For example, the subsurface fail safe shut safety valve (74) of FIG. 91, operated with a control line (79) connected in series or independently to each valve, and whereby, for example, the arrangement may be formed by engaging valves to the upper and lower ends (90) of the manifold crossover (23C or 23Y) member of FIGS. 22-25.

(114) A check valve (84), located at the lower end of the well, controls one way flow of the fluid mixture (38) into a conduit string (2, 2A) at the lower end of the manifold string (70B, 70L), which can be produced (34) into various arrangements of passageway member spaces formed by concentric conduit string (2,2A, 2B of FIGS. 14-16, 20 and 43, 2C of FIGS. 43, 54 and 59) members, the first annular passageway (55 of FIG. 1) and/or salt cavern walls (1A of FIG. 1). A liquid interface (118) and/or water interface (117 of FIG. 43) can result from the pressure applied to, or released from, the passageway member space by a flow controlling member (61), such as the valve tree (10A), and a substantially gaseous naturally expanding flow stream (120) can be extracted (34) through a conduit (2, 2A) for urging a substantially liquid flow stream (119). Alternatively, the substantially liquid flow stream (119) can be urged by: natural subterranean pressure, a motor and fluid pump (69), a surface pump (116), an electrical submersible pump and/or other flow controlling members, through a conduit string (2, 2A, 2B) passageway or concentric passageway that can be formed between the conduit strings and/or the passageway through subterranean strata.

(115) The depicted single well manifold string (70L), or a plurality of similar wells, stemming from, for example, the manifold string member (70F) of FIGS. 100-105, can be installable with a managed pressure conduit assembly (49) with inner (50) and outer (51) concentric conduit strings and slurry passageway fluid stream crossover tool (58) can be usable to, for example, provide larger conduit sizes than are generally practiced during well formation for subterranean separation purposes. Once engaged to the wellhead and/or tree, the managed pressure arrangement becomes a manifold string (70, 76) with concentric strings (2, 2A, 2B, 2C) and manifold crossovers (21, 23) members to perform injection or production functions, usable to configure one or more wells to separate fluid mixture streams (70L) for individual or junctions of wells (51A of FIGS. 50-52) applications similar to the manifold string (76L) of FIG. 123.

(116) Manifold strings (70L, 76L) of FIGS. 43 and 123, respectively, are usable for separation of a fluid mixture into a plurality of simultaneously flowing fluid mixture streams from a single well, from one or more vertically and/or laterally separated subterranean regions, or from caverns where large suitable salt deposits are usable for solution mining a separation space, that can be usable for wells or a transportation pipeline. Larger separation spaces are formable with a managed pressure string of the present inventor or may be formed by various other methods, such as using subterranean separation to solution mine cavern walls (1A) with produced water or as described in methods of the present inventor, or using abundant available water sources such as the ocean. In instances where waste water is produced or readily available, the present invention can be usable to perform simultaneous production, solution mining, underground storage and/or separation of a plurality of fluid mixture streams, entering and/or leaving a subterranean space or proximal region accessed through a manifold string.

(117) Referring now to FIGS. 44 and 45, elevation cross-section and process control diagrammatic views, respectively, of an embodiment (70C) of subterranean manifold string member (70), with selectable internal velocity string manifold crossovers (23), fracture propagation chamber junction manifold crossovers (21) and motor and fluid pump (69) flow controlling members (61) are shown. The Figures illustrate an inner concentric string (2) and outer concentric string (2A) extending downward from a wellhead (7) and valve tree (10A). During well construction, a chamber junction manifold crossover (21) can be usable to urge (28A) proppant into support fractures (18A), with, for example a shale gas or waste disposal well, through a perforated liner (19) that is cemented (20) within the strata bore (17) and engaged via a liner top packer to the final cemented casing (3), within which the manifold string (70C) is engaged with a packer (40). Later, in the well's life cycle, the manifold crossovers (23A) can be usable to reconfigure and form a velocity string to accelerate production velocity and to prevent water production from inhibiting, for example, associated hydrocarbon production.

(118) The arrangement also can be usable to access a first annular passageway (55) through the manifold string (70C of FIGS. 44-45), to, for example, provide waste injection disposal, wherein the manifold crossover (23) that is adjacent to the shallow strata fracture (18) can be formable from various manifold crossover members, for example a chamber junction (21) and manifold crossover arrangement (23C and 23Y of FIGS. 22-25). A plug (25A of FIGS. 22-25) can be usable to crossover fluid communication of the passageways (24, 25), with the chamber junction crossover (21) usable to access the first annular passageway (55) from the inner passageway (25), whereby production from the velocity string manifold crossover (23A) flows through the concentric passageway (24) and axially upward, while waste water below a water interface (117), from surface separation (115) of the production, can be pumped (116) and injected (31) through the valve tree (10A) and chamber junction crossover (21) axially downward to operate a fluid motor and pump (69) urging production axially upward.

(119) The manifold string (70B, 70L, 70C) arrangements of FIGS. 43-45 describe various possible arrangements for subterranean separation and subsequent waste disposal. For example, a substantially liquid flow stream (119) can be further processed and pumped (116) for disposal into an annulus shown as a dashed line in FIG. 42. Then, the flow stream (119) can be pumped through an annulus valve (81), within the annulus between the intermediate (15) and final cemented casing (3), that can be controlled by a casing shoe (16) for resisting fluid flow into an outer annulus, and injected (31) through the valve tree (10A), as shown in FIG. 44. The waste water can be disposed by pressure communicating (28) to the point of fracture propagation (30) within a subterranean strata feature. As shown in the Figures, extracted subterranean pressurized fluids, such as compressed gas, high pressure production or the injected waste fluid mixture (31 of FIG. 44), can be usable to operate the fluid motors and fluid pumps (69).

(120) The manifold string (70L) arrangement of FIG. 43 can be usable with a chamber junction manifold crossover (21) to selectively communicate with a subterranean hydrocarbon interface (118) that is separated from a subterranean water interface (117). One or more submersible pumps (69) operated by, for example, electricity, expanding compressed gas from the separation process, or injected fluids (31 of FIG. 44), can be usable to assist selective removal of liquid hydrocarbon or water between the various interface layers. If motors and pumps are not desired, the gas stream may simply be closed in, to allow pressure to build within the well to u-tube the fluids through one or more passageway members.

(121) Manifold string (70C) of FIGS. 44 and 45 can be usable with a chamber junction manifold crossover (21) to selectively communicate fracture propagation fluid and proppants during well formation. After which, the chamber junction manifold can be used for selective extraction from desired subterranean regions or water shut-off with, for example, gas expansion from a shale gas deposit usable to drive fluid motors and fluid pumps (69) for injecting waste fluids into the shallower strata feature shown. FIG. 44 shows a manifold valve crossover (23F) that can be adapted for use with a chamber junction and further manifold crossover (23) for selective control of fluid mixtures flow streams in the manifold string.

(122) FIGS. 46 and 47 depict elevation cross-section and process control diagrammatic views, respectively, of a prior art gas lift arrangement. The Figures show a wellhead (7) from which a fluid mixture (38) can be produced (34) through tubing (2) and a valve tree (10), wherein a substantially liquid fluid flow stream (119) can be lifted through the innermost concentric passageway (25) with the use of a substantially gas fluid stream (120). The lifting occurs by injecting the gas stream from the surface through an annulus valve (81) and into the concentric passageway (24), formed between the tubing (2) and casing (3) that is cemented (20) into the strata bore hole (17). The injection passes through the passageway through subterranean strata (52) to a gas lift valve (84), placeable through the innermost passageway (25), to create a fluid mixture of liquid and gas, thus increasing the fluid stream velocity and reducing the sandface pressure exerted on the producing formation to increase production (34) above what is possible using normal producing pressures. A subterranean fail-safe safety valve (74) can be operated with a control line (79), valve tree (10), one way gas lift valves (84) and annulus valve (81) to be usable to selectively contain subterranean pressures in the well and to urge production (34), provided surface processing and/or gas is available for lifting production.

(123) Conventional gas lift arrangements are widespread, but require a surface supply of injectable gas that, together with the associated surface facilities, represent a significant economic and logistical hurdle for remote and/or environmentally sensitive developments. For many hydrocarbon developments, the present invention is usable to selectively control and re-inject subterranean separated gas at locations suited for extraction, wherein a surface supply of injection gas and associated surface facilities are not required.

(124) FIGS. 48 and 49 depict elevation cross-section and process control diagrammatic views, respectively, of an embodiment (70D) of a subterranean manifold string member (70), usable to separate a fluid mixture of liquid and compressed gas into substantially liquid and substantially gas fluid streams, The separated streams can be usable to selectively re-inject and to gas lift the substantially liquid flow stream, particularly where surface processing and gas injection are uneconomical and/or impractical. For example, the embodiments shown in FIGS. 48 and 49 can be used economically in remote subsea and marginal developments, that are lacking infrastructure.

(125) A fluid mixture (38) can be produced (34) through a conduit (2), engaged by a packer (40), to the passageway through subterranean strata (52), comprising the production casing (3) cemented (20) into the strata bore (17) and conductor casing (14). The fluid mixture (38) can reach a pressure activated valve (63) that controls the radial passageway of a manifold crossover (23W) embodiment, usable with a one-way valve and venturi (85) manifold crossover (23H) embodiment to vacuum liquid from the gas lift separation space. Pressures within the concentric passageway (24) can be selectively controlled by a choke valve (77), located on the valve tree (10A), against a separated substantially gas fluid stream (120), that can be all or partially diverted through gas lift valve (84) manifold crossover (23G) embodiments to aid the lifting of a substantially liquid fluid stream (119) taken from the concentric passageway (24), below the liquid level (118) and through the venturi (85) manifold crossover (23H).

(126) To maintain well integrity if the valve tree (10A) fails, a subterranean valve (74), operated with a control line (79), and the pressure activated valve (63) manifold crossover (23W) contain the ingress of subterranean pressurized fluid mixture (38), wherein similar to a conventional gas lifted well, only the limited inventory in the annular space is uncontained. The addition of an annular safety valve or an additional valve controlled manifold crossover (23F) usable to control both the innermost and concentric passageways can be usable to pressure contain the space, if required.

(127) Referring now to FIGS. 50, 51 and 52, elevation diagrammatic views of various manifold string (76) plurality of wells embodiments (76A, 76B, 76C), usable with substantially hydrocarbon and substantially water wells, are shown as production/waste-fluid-injection, water-flood and solution mined/storage wells, respectively, using a junction of wells (51A) with a plurality of wells extending downward from a single main bore (6) and wellhead (7). The plurality of wells may access subterranean injection features (103), relatively horizontal or folded (94) reservoirs (95), and salt deposits (5) disposed between subterranean formations (106).

(128) Manifold string (76A, 76B) member arrangements of hydrocarbon or geothermal wells, usable for water or produced water disposal and water floods, can inject water into a feature (103) or relatively horizontal water drive (104) reservoir, while producing from a folded (94), faulted, fractured and/or water driven reservoir using one or more of a plurality of wells to dispose of waste water and/or to increase reservoir pressure for production of hydrocarbons or steam from a geothermal reservoir.

(129) Manifold string (76C) member arrangements can be usable for solution mining and selective access of gravity separated hydrocarbon products within the space of cavern walls (1A) of a salt deposit (5), that is sealed at its upper end by the final cemented casing (3) and casing shoe (16). Solution mining of a cavern space may use ocean, waste or produced water from various other embodiments. Substantially hydrocarbon fluid mixtures of liquids, gases, and/or solids from wells or pipelines can be separated, stored and/or selectively accessed within a cavern space with the use of manifold crossovers selectively flowing different fluid mixtures from between specific gravity separated fluid levels (105), using, for example, a chamber junction manifold crossovers (21). Substantially water fluids sinking to the lower level (104) are usable to simultaneously displace storage, increase cavern pressure and/or solution mine the space.

(130) Referring now to FIGS. 53 to 59, wherein methods and apparatus shown in FIGS. 53 and 58 are adaptable with the manifold crossover (23J) of FIGS. 54-57 to form the manifold string (76K) of FIG. 59, to complete the subsea well of FIG. 53.

(131) FIG. 53 depicts an elevation cross-section view of a subsea wellhead (7), positioned above the sea floor (122), that can be usable with manifold strings (70A, 70B, 70C) of FIGS. 50-52 and the adapted chamber junction manifold crossover of FIG. 59. The Figure shows subsea connectors (107), a wellhead (7) and a single main bore (6), that is located within a strata formation (106) and which comprises a chamber junction (43) engaged to the wellhead, with exit bores extending to the well's lower end. The ends (90) of the exit bore conduits (39) can be engaged to a plurality of wells.

(132) Referring now to FIGS. 54 and 55, a plan above an elevation view is shown, with dashed lines showing hidden surfaces of a manifold crossover (23) embodiment (23J). Figure 54 depicts innermost passageway connectors (26), usable to connect the innermost passageway above and below the manifold crossover with the radial passageways (75), to fluidly communicate with orifices (59) that can be connected to a concentric passageway. As shown in the Figures, receptacles (45) can be used to selectively control the innermost passageway and/or radial passageway with a flow controlling member, for example, with as a straddle (22 of FIG. 93A) or plug (25A of FIG. 93) placed through the innermost passageway and engaged with the receptacle. A plurality of concentric conduits (2A, 2B, 2C of FIGS. 54 and 59) can be usable to form a plurality of concentric conduit passageways for connection to one or more of the orifices (59), from a radial passageway (75).

(133) FIGS. 56 and 57 depict an isometric view with line K and a magnified view within line K, respectively, showing a cut-out section of the manifold crossover (23J) of FIG. 54. The Figures depict orifices (59) of the radial passageway (75) and receptacles (45), that can be usable for selective engagement of flow controlling members to control the flow of fluid mixture streams.

(134) Referring now to FIGS. 54-57, concentric passageways (24, 24A, 24B, 25, 26, 53, 54, 55) can be formed between concentric conduits (2, 2A, 2B, 2C, 50, 51) and the passageway through subterranean strata (52 of FIG. 53), and each orifice can be configurable to individually access a different concentric passageway (24, 24A, 24B). Flow streams can flow into (32, 35) the innermost passageway, directly (32), from a first concentric passageway or, indirectly (35), from a first concentric passageway through another secondary concentric passageway. Alternatively, flow streams can flow into (33, 37) the concentric passageway through an orifice (59), either directly (33) or indirectly (37) from a first concentric passageway or from a first concentric passageway through a secondary concentric passageway. This allows any configuration or flow orientation between passageways with a plurality of manifold crossovers (23J), which can be engaged in series with the orientation of the radial passageway that can be changed, for example, by reversing or turning over one of the manifold crossovers. The orifices (59) can be connected to form fluid communication between the passageway members, and the orifices can be engagable to a plurality of concentric passageway members (25, 24, 24A, 24B, 55), within and between an innermost conduit (2) and a plurality of concentric conduit (2A, 2B, 2C) strings and the passageway through subterranean strata (52).

(135) Referring now to FIGS. 58 and 59, isometric views of a chamber junction manifold (43A) and manifold string embodiment (76K), respectively, are shown. The chamber junction manifold (43A) comprises a chamber wall (41) with engaged (44) exit bore conduits (39), that can be controlled by valves (74) and seal stacks (66) that can be engagable to another chamber junction (43 of FIG. 54). The chamber junction shown in FIGS. 58 and 59 includes a landing plate (67) and indexing key (65). The chamber junction manifold (43A) can be adapted with a plurality of concentric strings (2, 2A, 2B, 2C) and a manifold crossover (23K) of FIG. 59 for replacing the valve (74) arrangement of FIG. 58. The manifold string (76K) shown in FIG. 59 and formed by the adaptation, can be usable to selectively control a plurality of simultaneously flowing fluid streams, when placed, for example, in the subsea well of FIG. 53.

(136) Referring now to FIGS. 60 to 66, which illustrate another chamber junction manifold adaptation that uses a plurality of manifold string set members of the present invention. The chamber junction manifold (43A) of FIGS. 60-61 is adaptable to form the manifold crossover (23L) embodiment of FIGS. 62-66, which can be used in combination with the manifold crossover (23X) embodiment to form a manifold string embodiment (76J), that can be usable to perform the same function with concentric conduits (2, 2A) of FIGS. 62-66 instead of parallel conduits (78 (also shown in FIG. 59) and 71 of FIGS. 60-61). Concentric conduits can be usable to improve flowing capacity within the passageway through subterranean strata for producing and injecting simultaneously flowing fluid mixture streams of various velocities, whereby a dual bore valve tree, necessary for the chamber junction manifold (43A) of FIGS. 60-61, can be replaced with a single bore valve tree, for the manifold string (76J) of FIGS. 62-66, for easier placement of flow controlling members within the innermost passageway, by, for example, removing the need for a plurality of wireline (4A of FIG. 3) rig-ups, which are needed for dual bore valve trees.

(137) Chamber junction members can comprise a chamber bottom (42) with a receptacle (for example 45A shown in FIG. 33 if an exit bore extends axially downward or 45C of FIG. 66) for engagement of a bore selector (47 of FIG. 95-96) extension (48 of FIGS. 95-96), that can be used to complete the fluid and apparatus guiding surface (87) within the chamber junction. Chamber walls (41) can be engaged (44) to the exit bore conduits (39) and further engaged to upper end innermost passageway connectors of a manifold crossover (23X), with a receptacle (45) for engagement of flow controlling members (25A, 61) and a radial passageway (75) for fluid communication between passageways. As shown in the Figures, the assemblies ends (90) can be engagable to conduits (2, 2A, 71, 78) of a single main bore at the upper end and plurality of well conduits at the lower ends.

(138) FIGS. 60 and 61 depict plan and isometric views, respectively, of a chamber junction manifold crossover (43A) usable for simultaneous injection and production flow streams. As shown in the Figures, the main bore first conduit (71) and main bore second conduit (78) are parallel and access segregated portions of the chamber with valves (74), below controlling exit bore conduits engagable, with seal stacks (66), to other chamber junctions (43 of FIG. 53). The chamber junctions of the present inventor shown in FIGS. 60 and 61 allow, for example, the simultaneous production from two wells and injection into one well, similar to the manifold string (76B) of FIG. 51.

(139) Referring now to FIGS. 62 and 63, plan and elevation views, respectively, with dashed lines showing hidden surfaces of a manifold string (76J) and chamber junction manifold (43A), with a manifold crossover embodiment (23X) for adapting a chamber junction (43), are shown. The Figures illustrate an inner concentric string (2) and outer concentric string (2A) which are equivalent in function to a main bore first conduit (71) and a main bore second conduit (78), respectively, wherein simultaneous fluid mixture flows into (32, 35) one of the three innermost passageway members (25, 26), either directly (32) or indirectly (35) from a concentric conduit passageway (2B, 2C of FIGS. 54 and 59), or into (33, 37) the concentric passageway (24) through the orifice (59), either directly (33) or indirectly (37), and then through concentric passageways (24, 24A, 24B, 55), when additional concentric conduits are present (2B, 2C of FIGS. 54 and 59) at the upper end (90A).

(140) A bore selector (47 of FIGS. 95-96) extension (48 of FIGS. 95-96) can be engagable with the chamber junction bottom receptacle (83), wherein the guiding surface (87) is completed across a single innermost passageway (25), blocking other innermost passageways to, for example, place a plug (25A of FIG. 66) to divert flow into (33, 37) the concentric passageway (24) or into (32, 35) the lower left innermost passageway (25).

(141) FIG. 64 depicts an isometric view of the manifold string (76K) and manifold crossover (23X) of FIG. 62. FIG. 64 shows the inner concentric string (2, 71) and outer concentric string (2A, 78), with dashed lines showing an optional additional concentric conduit (2B) end location (90A) and associated optional orifice (59A), which can be usable with other manifold crossovers (23Y of FIGS. 14-16, for example) that are engaged to the upper end (90). The engagement can provide fluid communication between the lower left innermost passageway (25 of FIG. 62) to alternate passageway members using crossover members of the present invention.

(142) Referring now to FIGS. 65 and 66, plan and elevation cross-section views with and along line L-L, respectively, of the manifold string (76K) and manifold crossover (23X) of FIG. 62 are shown. The Figures include a flow controlling member (61), that is shown, for example, as a plug (25A), installed through the innermost passageway of the inner concentric string (2) using a bore selector. As depicted in the Figures, the outer concentric string (2A) is placed in fluid communication through the chamber junction manifold (43A) and radial passageway (75) of the manifold crossover (23X). Alternatively, a straddle (22 of FIG. 93A) can be engaged to one or more of the receptacles (45) to cover the radial passageway and to selectively commingle fluid communication between all three innermost passageways (25) extending from the exit bore conduits (39) of the chamber junction (43). Various combinations of injection (31) and production (34) between the member passageways (25) can be usable to selectively control simultaneously flowing fluid mixture streams.

(143) FIGS. 67, 67A and 68 show elevation diagrammatic views of various valve (74) flow control and manifold string (70, 76) embodiments (76D, 76E and 70E respectively). The Figures show valve flow controlling members (61) above, below, and between chambers junction (43) and manifold crossover (23) members to selectively control the innermost passageway (25) flow stream that is passing through the straddle (22) and concentric passageway (24), between the inner concentric string (2) and outer concentric string (2A), which is shown blocked from the innermost passageway and diverted through a radial passageway of the manifold crossover with a blocking plug (25A). FIG. 67 includes a manifold valve crossover (23F) that can be adapted with a chamber junction and, further, a manifold crossover (23) with a plug (25A) and straddle (22) for forming the manifold string embodiment (76D) of FIG. 67. FIG. 67A includes a chamber junction (43) and manifold crossover (23), with a plug (25A) and straddle (22) located above selectively controlled valve flow controlling members (61) engaged between conduits of each exit bore string. For forming the manifold string embodiment (76E) of FIG. 67A. FIG. 68 includes a manifold crossover (23M) embodiment with concentric conduits (2, 2A) at upper and lower ends, with intermediately selectively controlled valve flow controlling members (61) engaged to exit bore conduits (39), for forming the manifold string embodiment (70E) of FIG. 68.

(144) Selectively controlled and/or fail-safe shut valve manifold strings (70E, 76D, 76E) are usable, for example, in hydrocarbon or geothermal wells where the unplanned release of flammable or superheated production is unacceptable, should other surface containment equipment fail to operate.

(145) Referring now to FIGS. 69 to 74, the Figures illustrate manifold crossover embodiments (23N, 23P) combinable as building blocks through integral construction, or as members with intermediate conduits and member passageways, to form a new manifold crossover (23Q) embodiment. The new embodiment (23Q) includes an increased number of selectively controllable reconfigurations, which is more than either of the crossovers, and further demonstrates that various combinations of members may form new embodiments of the present invention.

(146) Referring now to FIGS. 69 and 70, a plan view above an elevation view and an isometric view, respectively, of an embodiment of manifold crossover (23P) is shown, with dashed lines depicting hidden surfaces. The Figures illustrate flow orientations (32) through a radial passageway (75), between innermost passageway connectors (26). Blocking the orifices (59) with, for example, a straddle can prevent flow through the radial passageway or placement of, for example, a blocking plug, can divert flow through the radial passageway.

(147) FIGS. 71 and 72 depict a plan view above an elevation view and an isometric view, respectively, of an embodiment of manifold crossover (23N), with dashed lines depicting hidden surfaces, showing flow orientations (32, 33) through a radial passageway (75), between innermost passageway connectors (26) and orifices (59), that are engagable with a concentric passageway. Passageway members can be blocked, when covered by a straddle, and diverted through when a blocking member is selectively placed. Intermediate flow diverting apparatus, using various flow controlling members, for example, fixed or variable chokes and pressure activated valves, can be usable to selectively control a portion of the flow through passageway members.

(148) Referring now to FIGS. 73 and 74, a plan view above an elevation view and an isometric view, respectively, of a manifold crossover (23Q) embodiment is shown. The embodiment (23Q) is formed by combining other manifold crossovers (23P, 23N of FIGS. 69-72), with cut-out and dashed lines depicting hidden surfaces. The Figures illustrate selectively configurable flow streams, that flow directly (32) to the innermost passageway or indirectly (35) through the upper right intermediate commingled innermost passageway (26) or, alternatively, directly (33) into the concentric passageway or indirectly (37) through lower innermost passageway connector (26) intermediate commingled passageway. Orifices (59) are shown that can be engagable to one or more concentric passageways, between two or more conduits, wherein flow controlling members are selectively placeable and/or configurable across orifices of the radial passageways or other member passageways to selectively affect flowing fluid streams, passing through the manifold crossover (23Q).

(149) FIG. 75 depicts an isometric view of the manifold crossover of FIGS. 17 to 19, which can be usable with the adapted chamber junction (43) of FIGS. 76 to 80 and the radial passageway (75) orifices (59), engaged to the connecting conduit (93) of FIG. 81, to form the manifold string (76F) of FIG. 82.

(150) Referring now to FIG. 76, a plan view of an embodiment of an adapted chamber junction (43), with dashed lines showing hidden surfaces, is shown. The Figure illustrates the inner concentric string (2) communicating with innermost passageways (25) of the exit bore conduits (39) and outer concentric string (2A) for forming a concentric passageway (24), with orifices (59) engagable to a connecting conduit (93 of FIG. 81), to form the manifold string (76F) of FIG. 82.

(151) FIGS. 77 and 79 depict plan views, with lines M-M and N-N above cross section elevation views and along lines M-M and N-N, respectively. The embodiments shown in the Figures are associated with the manifold crossover of FIG. 76, with detail line P of FIG. 77 associated with FIG. 78. Break lines, representing removed portions, show an adaptation of a chamber junction (43), usable with the flow controlling members of FIGS. 75 and 81 to form the manifold crossover (23R) of FIG. 82.

(152) Referring now to FIGS. 78 and 80, a magnified view of the portion of the adapted chamber junction (43) within detail line P of FIG. 77 and an isometric view, respectively, are shown. The Figures depict the inner concentric string (2) and outer concentric string (2A) members forming a concentric passageway (24), with orifices (59) engagable to the upper end (90 of FIG. 81) of the connecting conduit (93 of FIG. 81), and with the lower end (90 of FIG. 81) engaged to the manifold crossover (23D of FIG. 75) orifices (59 of FIG. 75), to form the manifold string (76F) of FIG. 82. A receptacle (83) is shown in the chamber bottom (42) for the orientation and engagement of the bore selector (47 of FIG. 95-96), which can be usable to communicate between the innermost passageways (25) above the chamber (41) and the innermost passageways of the exit bore conduits (39), to provide selectable control.

(153) Referring now to FIG. 81, an isometric view of a connecting conduit (93), usable between the kidney-shaped chamber junction orifices (59 of FIG. 76) and small diameter orifices (59 of the FIG. 75) of the manifold crossover (23D of FIG. 75), is shown, which can be usable to form the manifold string (76F) of FIG. 82.

(154) FIG. 82, an isometric view of an embodiment (76F) of a manifold string (76) associated with FIGS. 106-116, is shown. The embodiment (76F) is assembled from the associated manifold crossover member parts of FIGS. 75, 80 and 81 with flow controlling members (74 and 91 of FIGS. 91 and 94, respectively). The Figure depicts a manifold crossover embodiment (23R) formed by the combination of members comprising a chamber junction, a nipple (91 of FIG. 94) or selected nipple receptacle (45 of FIG. 94), connecting conduit (93 of FIG. 81), and a manifold crossover (23D of FIG. 75).

(155) As fluid mixtures of liquid and/or gas may contain abrasive solids, fluid mixtures flowing at varying velocities may erode paperwork functional variations of manifold crossovers with longer more gradual flow path deviations are needed for various applications, such as solution mining and high pressure hydrocarbon fluid mixtures with high velocities.

(156) Referring now to FIGS. 83 to 87, the Figures depict a manifold crossover embodiment (23T) usable to minimize frictional resistance to flow in high velocity or high erosion environments. As such long sweeping embodiments are more difficult to comprehend than shorter versions with right angles, various embodiments of manifold crossovers have been described with emphasis. However it should be understood that within the scope of the appended claims, that previously described manifold crossovers embodiments are constructible from chamber junctions (21, 43) of the present invention to minimize frictional resistance in high velocity and high erosion environments similar to 23T of FIGS. 83 to 87 for plurality of well applications or 23Z and 47A of FIGS. 117 to 122 for single well applications. More than two exit bores and/or more than one radial passageway blisters and/or segregated concentric passageways can be usable with two chamber junction manifold crossovers (23T) having exit bore ends engaged, similar to the crossover 23M of FIG. 68, for concentric conduit applications. For example, straddles, blocking plugs, and pressure controlled, acoustically controlled, fluid pulse controlled, and/or choking flow control devices can be placed within exit bore receptacles to selectively control member passageways.

(157) Referring now to FIG. 83, an isometric view of an embodiment of adapted chamber junction manifold crossover (23), associated with FIGS. 84 to 87, is shown. The Figure illustrates an inner concentric string (2), outer concentric string (2A) or second main bore conduit (78) with ends (90), that can be engagable to conduit strings of a single main bore above a chamber junction (43), for forming a manifold (43A) with the addition of receptacles and a radial passageway (75) blister, between the exit bore conduits (39) and the chamber junction bottom (42).

(158) FIGS. 84 and 86 depict plan views above elevation cross-sectional views with, and along, lines Q-Q and R-R, respectively, with break lines removing portions of the assembly associated with cross sections in FIGS. 85 and 87 isometric views, showing the manifold crossover (23T) of FIG. 83. The Figures illustrate the placement of a flow controlling member, shown as a cable (11 of FIG. 3) placeable and retrievable blocking plug (25A), that can be placeable through the inner concentric string (2) innermost passageway (25) with a bore selector (47 of FIG. 96), usable to complete the innermost passageway guiding surface (87) and excluding other exit bore plug flow controlling members engaged with a selected nipple profile receptacle (45) for blocking fluid communication within one exit bore conduit (39) innermost passageway (25). The concentric passageway (24) flow stream may communicate from below the plug, directly (32, 33), with the exit bore conduit passageway or, indirectly (35, 37), with various other manifold crossovers (21, 23) engagable to the upper end (90) of the chamber junction, through the radial passageway (75) blister. Commingled flow within the chamber junction manifold (43A), from both exit bores, can be operable by placing a straddle (22 if FIG. 93A) across the orifice (59) of the radial passageway (75).

(159) Referring now to FIGS. 85 and 87, the Figures show projected isometric views, with cross sections associated with FIGS. 84 and 86 and break lines of the manifold crossover (23T) of FIG. 83. The Figures show isometric views from different orientation perspectives of the radial passageway (75) blister flow passageway member and the flow controlling member (61), shown as a blocking device (25A). Other flow controlling members, such a pressure activated one-way valve, can be usable to feed a substantially lighter, specific-gravity, fluid-stream, first well into a heavier flow-stream, second well to reduce hydrostatic pressure on the second well and, thus, increase flowing velocity.

(160) Chamber junction crossovers, of similar construction, with radial passageway blisters (75) and discontinuous exit bore conduits with receptacles (24) can be usable to replace connecting conduits (93 of FIG. 81) and manifold crossover (23D of FIG. 75) or to replace the manifold crossover (23R of FIG. 82) in the manifold string of FIGS. 88-116 when, for example, erosion or flow cutting of an assembly from flow streams of higher velocity is of concern. For example, such concerns include during solution mining in substantially water wells, or proppant fracture propagation operations in shale gas or low permeability sandstone reservoirs, in substantially hydrocarbon wells.

(161) Referring now to 75-82 and 88-116, the Figures show member embodiments usable to construct and complete a well with a manifold string (76F) member, that can be usable within a chamber junction member (43 of FIG. 88-89 adaptable into a managed pressure conduit assembly (49) manifold string 70F during installation) and various flow controlling members to form an adapted manifold string (76G of FIGS. 106-116) member.

(162) FIGS. 88 and 89 depict isometric and magnified views with and within detail line S, respectively, of a chamber junction (43), with dashed lines showing hidden surfaces. The embodiments shown in the Figures can be usable within a managed pressure string (49 of FIGS. 97-105) or as a member of a junction of wells (51A of FIGS. 51-54 and 106-116). The Figures include a chamber (41), chamber bottom (42), and exit bores usable with a bore selector (47 of FIG. 90).

(163) Referring now to FIG. 90, an isometric view of a bore selector (47), that can be usable with the chamber junction of FIGS. 88 and 89, is shown with dashed lines, illustrating hidden surfaces, depicting the guiding surface (87) for communicating fluids and the apparatus through its lower orifice (88), wherein a receptacle (45B) is usable to place, rotate and remove the bore selector (47).

(164) FIGS. 91, 92, 93, 93A and 94 show examples of valve, packer, plug, straddle and nipple prior art flow controlling members, which can be usable with the present invention, respectively. FIG. 91 depicts a plan view, with section line T-T above an elevation view along section line T-T of a subterranean valve (74) of flapper (127) type, which comprises a flow controlling member (61). FIG. 92 depicts an isometric view, with a quarter section removed and detail line U above the magnified portion within line U, of a production packer (40) flow-controlling member (61) with engaging connectors (60) and sealing engagement (97), that can be activated by pressure shearing pins (92). FIG. 93 depicts an isometric view of a plug (25A) flow controlling member. FIG. 93A depicts a plan view, with line AK-AK above an elevation cross section along line AK-AK, of a straddle (22) flow-controlling member (61), with sealing apparatus (97) and snap-in (96) engaging connectors (60). FIG. 94 is a plan view, with section line V-V above an elevation cross section along line V-V, showing a nipple profile (91) flow-controlling member (61) with a receptacle (45) for engagement of various other flow controlling members. The upper and lower ends of the flow controlling members of FIGS. 91-94 can be engagable between conduits of concentric conduit strings of the present invention.

(165) Referring now to FIGS. 95 and 96, the Figures depict an isometric view and a right adjacent to a front view, respectively, of a bore selector (47), with dashed lines illustrating hidden surfaces. The bore selectors shown FIGS. 95 and 96 include engagement receptacles (45B) and bore selector extensions (48), and the bore selectors can be usable with various adapted chamber junction crossover embodiments of the present invention for example, the embodiments shown in FIGS. 106 to 116.

(166) Referring now to FIG. 97, an isometric view with detail lines AE and AF associated with FIGS. 98 and 99, respectively, of an adapted chamber junction is shown. The chamber junction shown in FIG. 97 can be usable to form a managed pressure conduit assembly (49 of FIGS. 100-105) and manifold string member embodiment (70F of FIGS. 100-105). The Figure includes dashed lines showing hidden surfaces.

(167) FIGS. 98 and 99 depict magnified views of a portion of the chamber junction (43) within detail lines AE and AF of FIG. 97, with dashed lines showing hidden surfaces. The Figures illustrate a chamber junction (43 of FIGS. 88-89) adapted with whipstocks (124) extending from exit bore conduits (39), that can be usable to laterally separate bored strata passageways, forming innermost passageway connectors (26) of a manifold crossover (23), which can be usable for boring with a casing bit (125). Circulation of a fluid slurry can occur through bit orifices (59) during well construction. The chamber bottom (42) orifices (59) can be usable for engaging a radial passageway (75 of FIGS. 102 and 104) of a slurry passageway apparatus (58 of FIGS. 100-104), whereby the assembly member can be usable to form a manifold crossover (23U of FIGS. 102-104).

(168) Referring now to FIG. 100, the Figure shows a plan view with line AG-AG associated with FIG. 101, of an adapted slurry passageway tool (58). The Figures includes the adapted chamber junction of FIG. 97 forming a managed pressure conduit (49) member embodiment (70F) of a manifold string (70), which can be usable to form a plurality of well passageways through subterranean strata, usable to form further embodiments (for example 76G of FIGS. 106-116).

(169) FIG. 101 depicts an elevation cross-section view along line AG-AG, associated with FIG. 102 of the manifold string (70F) of FIG. 100, with break lines indicating missing portions. The Figure shows an inner concentric string (50), outer concentric string (51), rotary connector (72) and slurry passageway apparatus (58) for placing and securing the member (70F) with, for example, simultaneously circulated, separate, cement and drilling slurry fluid-mixture flow streams of varying velocities, within the passageway through subterranean strata.

(170) Referring now to FIG. 102, the Figure shows a projected isometric view of FIG. 101 with cross-sections at associated break lines of FIG. 101, and with detail lines AH, AI and AJ associated with FIGS. 103, 104 and 105, respectively, of the manifold string (70F) of FIG. 100. The Figure illustrates an adapted slurry passageway apparatus (58) usable as a manifold crossover member (23U) with a slip joint (126) flow controlling member used to facilitate spaceout of the concentric conduits of the assembly.

(171) FIGS. 103, 104 and 105 depict magnified views of the portion of manifold string (70F) of FIG. 102, within detail lines AH, AI and AJ, respectively. The Figures show an innermost passageway (2, 53) within an inner concentric conduit (50), with an upper end rotary connector (72), engagable to a drill string, that can be engaged at its lower end to the slurry passageway tool (58) engaged with mandrels (89) to a receptacle (45) in the outer concentric conduit (2A, 51). Direct (32, 33) or indirect (35, 37) flow streams, between the innermost passageway (25, 53) and concentric passageway (24, 54), can be usable within the inner (2, 50) and outer (2A, 51) concentric conduits for selectively controlling flow streams. The slurry passageway member (58) can be placeable and removable from the chamber junction (43). Whipstocks (124) can be usable to laterally separate more than one passageway through subterranean strata from a single main bore (6 of FIGS. 50-53 and 106-116). The remaining portion of the managed pressure conduit assembly (49) can be usable as an outer member of a junction of wells (51A of FIGS. 50-53 and 106-116).

(172) Referring now to FIGS. 106-116, the Figures depict a manifold string (70) member embodiment (76G) comprising a manifold crossover (23R of FIG. 82) member that can be engaged, with a packer (40 of FIG. 92) member, to a chamber junction member (43 of FIGS. 88-89) forming a junction of wells (51A) member. The Figures show the manifold crossover (23R) can be formed from a chamber junction manifold (43A) member that can be formed from a chamber junction (43 of FIG. 80), with nipple (91 of FIG. 94) members providing receptacles (45) engaged to the manifold crossover (23D of FIG. 75) member, which can be engaged to valves (74 of FIG. 91) usable to divert flow from one well of the junction of wells (51A) through the radial passageway (75) of the manifold crossover (23D). The left well flow stream can be diverted through a radial passageway (75) to the concentric passageway (24) by using a plug (25A of FIG. 93) member, engagable to the receptacle (45) and conveyable through the innermost passageway (25), while the flow stream of the right well can be urged through the innermost passageway (25), with both wells controlled by subsurface safety valves (74), between conduits of the innermost string (2) members and production packers (40) in the annular spaces (24A) at the lower end of the well.

(173) A valve tree and/or wellhead can be usable when engaged to the upper ends (90) of the single main bore (6) from which the two wells extend axially downward, at the junction of wells (51), to laterally and/or vertically separated subterranean regions, thereby providing the pressure integrity of two conventional wells through the single wellhead and main bore.

(174) Referring now to FIG. 106, the Figures shows a plan view with line X-X associated with FIGS. 107 to 111, with detail line W associated with FIG. 112, of a plurality of wells manifold string (76) embodiment (76G).

(175) FIGS. 107 to 111 show elevation cross-sectional views along line X-X of the manifold crossover of FIG. 106, with FIGS. 108, 109, 110 and 111 having lines Y, Z, AA and AB, respectively, associated with FIGS. 113 to 116 magnified views. The Figures illustrate the combination of manifold string members (23R, 76F of FIG. 82 and 43 of FIG. 88-89) with various flow controlling members (61) forming a junction of wells (51), with upper ends (90) engagable to conduits of a single main bore and/or wellhead. After construction, concentric conduits (50, 51) and associated passageways (53, 54, 55) can become production and/or injection conduits (2 or 71, 2A or 78, 51) with associated passageways (24, 24A, 25, 55), respectively. The chained dashed line, between upper and lower ends, represents a continuation of the apparatus across FIGS. 107-111, and the close lateral proximity of the two wells below the junction of wells (51A) is for illustration purposes, as wells below a junction of wells and single main bore have, generally, significant lateral separation to access both significantly vertically and laterally separated subterranean regions.

(176) Referring now to FIG. 112, a magnified view of the portion of manifold string (76G) within detail line W of FIG. 106, showing an inner concentric string (2), outer concentric string (2A), forming inner (25) and concentric (24) passageways with a chamber junction (43) about a chamber junction manifold (43A) for forming a junction of wells (51A). Various flow controlling members can be placed through the innermost passageway (25) using a cable (11 of FIG. 3) and wireline rig (4A of FIG. 3), with a bore selector (47 of FIGS. 95-96) that can be engagable with the receptacle (83) to selectively block one innermost passageway and to communicate with the other to convey apparatus for placement within. Alternatively, the bore selector (47 of FIGS. 95-96) engagable with the receptacle (83) can be used to simultaneously flow fluid mixture streams into (32, 35) the innermost passageway, or to communicate fluid into (33, 37) the concentric passageway (24), dependent on the other engagable manifold crossover members used.

(177) Referring now to FIG. 113, a magnified view of the portion of the manifold string (76G) within detail line Y of FIG. 108, is shown. The Figure illustrates the manifold crossover (23D) with a radial passageway (75) and nipple profile receptacle (45) between exit bore conduits (39) and inner concentric conduit strings (2).

(178) FIG. 114 depicts a magnified view of the portion of the manifold string (76G) within detail line Z of FIG. 109. The Figure shows subterranean valve (74) flow controlling members (61), that can be usable for selectively controlling the innermost passageway (25). For example, the Figure shows the subterranean valve (74) controlling members flapper (127) valve, with associated receptacles for isolating the flapper or setting other flow controlling members.

(179) Referring now to FIG. 115, the Figure depicts a magnified view of the portion of the manifold string (76G) within detail line AA of FIG. 110, showing inner concentric strings (2) passing through a chamber junction (43) bottom (42) with chamber walls (41) and associated exit bore conduits (39) functioning as a concentric conduit for a common concentric passageway (24). The common concentric passageway can be usable for injection (31) and circulated returns (34), prior to setting of the packer (40 of FIG. 116) and two innermost concentric passageways (25), also usable for injection (31) or production (34) to laterally and/or vertically separated subterranean regions.

(180) FIG. 116 depicts a magnified view of the portion of the manifold string (76G) within detail line AB of FIG. 111. The Figure shows exit bore conduits (39) engaged to the upper end of production packer (40) flow controlling members, which are shown engaged to concentric conduits (2A) with engagement devices (60) or gripping slips segments. The concentric passageway (24A) is shown blocked by the packer (40), and the innermost passageways (25) of the two wells extending from the chamber junction of wells (51 of FIG. 107) can be separatable to vertically and/or laterally separated subterranean regions.

(181) Referring now to FIG. 117, a plan view, with line AK-AK above an elevation view along line AK-AK, of a manifold crossover (23) is shown. The embodiment (23Z) of the manifold crossover (23) is shown comprising a chamber junction manifold crossover (21) member, depicting an adapted chamber junction (43) member with ends (90) engagable to other member conduit strings, comprising at least an outer (2A) and inner concentric conduit string (2) with an innermost bore (25) and upper end first receptacle (45) above a chamber junction bottom (42), that can be usable as an engagable second receptacle. The axial lower exit bore (39) can be isolated from the lateral sloping exit bore (39) by engaging a straddle or conduit across the first and second receptacles for sealing across the exit bore connection (44), to function as a bore selector for the axial aligned exit bore. Extending a straddle or sealing conduit from the first receptacle (45) to the third lower end receptacle (45) can separate the innermost (25) passageway from the concentric passageway (24), by sealing across the flow stream crossover orifices (59). Alternatively, a blocking flow-controlling member or bore selector can be engaged in the second receptacle (42) to cross flow streams from the innermost passageway, through the concentric passageway members (24, 24A), to the surrounding passageway member, which can include, for example, the first annular passageway. Flow below the blocking or bore selector can be diverable to the concentric passageway (24) through orifice crossover members, below the chamber junction crossover (21) bottom receptacle (42). The angular orientation of exit bores can be usable with high velocity or erosion prone fluid mixtures to prevent flow cutting of the manifold crossover (23Z).

(182) The chamber junction crossover (21) can be adaptable with an additional concentric conduit string member (2B), shown as a dashed line, forming an additional concentric passageway (24A) to which an exit bore (39) may communicate with or pass through moving the truncation (46) of the exit bore conduit (39) to the outermost conduit (2B). A plurality of exit bore conduits can selectively communicate with a plurality of additional concentric conduits using an exit bore conduit and bore selector to pass through intermediate passageway members to form new manifold crossover (23Z) member embodiments, that can be usable to communicate from the innermost bore (25) to any concentric passageway member. A plurality of manifold crossover members (23Z) can be combinable to form new manifold crossover members for fluidly communicating between a plurality of different concentric passageway members, through the innermost bore between the plurality of manifold crossovers (23Z).

(183) FIG. 118 depicts a plan view, with line AQ-AQ above an elevation view along line AQ-AQ with break lines indicating removed portions, of an adapted bore selector (47A) member embodiment, that can be usable in the manifold string members of FIGS. 119-122. The Figure illustrates a plurality of guiding surfaces (87) for an associated plurality of additional exit bore orifices (59 of FIGS. 119-122), usable to urge the bore selector within the innermost passageway using the pressure of a flowing fluid stream. An optional flow controlling member (61) shown, for example, as a one-way ball valve (84) can provide flow through the bore selector as it is pumped through the innermost passageway for alignment with an exit bore of the manifold string (70G of FIGS. 119-120).

(184) The adapted bore selector (47A) member embodiments can be combinable with other flow controlling members (61), for example, engagements (60) for receptacles (45 of FIGS. 119-122), conduit straddles (22) for blocking chamber junction exit bore passageways and/or blocking orifices (59) between member passageways, internal one way valves (84), or an engagement receptacle (45B) for a cable, jointed conduit work strings or coiled tubing operational tooling. The fluid circulated between the innermost passageway (25) and concentric passageway (24 of FIG. 119-122) can be usable to aid movement of the bore selector member within the innermost passageway to, for example, perform one or more stage fracture propagation operations within a shale gas deposit.

(185) Bore selector member embodiments may be pumped through the innermost passageway to engage orifices within the innermost passageway. Alternatively, the pumped bore selector embodiments can be suspended, for example, from a cable (11 of FIG. 3) and wireline rig (4A of FIG. 3) or a jointed conduit work string or coiled tubing rig, wherein the lifting capacity of a supporting rig can be supplemented by the ability to selectively control circulation of the bore selector, with simultaneously flowing fluid streams of varying velocity to remove or to place a fluid mixture. For example, fluid mixtures of liquids, gases and/or solids can be removed or placed during such operations as a proppant fracture operation for waste disposal, shale gas production, or the gravel packing of an unconsolidated reservoir.

(186) Referring now to FIGS. 119 and 120, a plan view, with line AP-AP above an elevation cross-sectional view along line AP-AP and an isometric view showing cross-sections along FIG. 119 elevation view break lines, respectively, of a manifold string (70G) member embodiment is shown. The Figures show a bore selector (47A) member with an engagement profile (60), engaged within a receptacle (45) of a chamber junction manifold crossover (21) member, with three exit bore orifices (59) aligned with the bore selector of FIG. 118. The Figures show an associated straddle that can be usable to crossover orifices, wherein fluid below the bore selector can be usable to circulate to (33) the concentric passageway (24), through the lowest manifold crossover (23) orifices, to aid placement of the bore selector, so that a fluid mixture of liquids, gases and/or solids can be communicated through the innermost passageway to (33) the first annular passageway, using the guiding surface (87) and exit bore conduit (39) forming a radial passageway (75) member.

(187) Placement of the bore selector within the innermost passageway for subsequent operations may occur, for example, using a wireline rig (4A of FIG. 3) and a cable (11 of FIG. 3) to selectively place the bore selector adjacent to exit bore conduits. Straddles (22) can be usable to cover orifices within the wall of the innermost conduit to form a circulated flow path within the manifold string passageway members (24, 25) for injection and/or extraction, for example, when propagating (28B of FIG. 123) subterranean fractures (18B of FIG. 123) through injection of proppant, followed by extraction of screened out proppants and subsequent selective flow of production and/or water shut-off.

(188) Alternatively, for example, urging a bore selector into alignment with an exit bore of a chamber junction crossover (21) member of a manifold string (70G), with, for example, coiled tubing or jointed conduit work strings, aided by pumping between passageway members (24, 25) through orifices in the inner concentric conduit (2), can be usable to place a fluid mixture of liquids and solid proppants that can be pumped through the coiled tubing and exit bore to propagate fractures. After which, fluid injected through the concentric passageway (24) passing through the check valve can be usable to flow fluid through the bore selector (47A) member, and into the innermost passageway member (25), to lift screened out proppants from the bottom up. In comparison, conventional practice requires the top downward venturi removal of screened out proppants. After the fluid flow has passed through the bore selector, the bore selector can be repositioned for directly circulating out proppants, as described in FIGS. 121-122. In this manner, multiple fracture propagation stages can be carried out without the need to remove the coiled tubing or jointed tubing conduit work strings from the well.

(189) FIGS. 121 and 122 depict a plan view, with line AN-AN above an elevation view along line AN-AN with dashed lines showing hidden surfaces, and an isometric view, showing cross-sections along break lines of the FIG. 121 elevation view, respectively, of a manifold string (70H) embodiment, that can be usable for removing solids from the innermost passageway. After aligning the bore selector (47A of FIGS. 119-120) and injecting or extracting a fluid mixture through an exit bore conduit (39) radial passageway (75), as described in FIGS. 119-120, the bore selector (47A) can be realigned with the orifices (59) in the innermost conduit (2) to provide a higher circulating flow rate between the passageway members (24, 25), while using a straddle wall (22) to block the exit bore conduit (39) radial passageway (75) initially used to place, for example, proppants.

(190) If, for example, a proppant frac job is carried out in a shale gas deposit with a bore selector first placed at the lower end of the manifold string (70G of FIGS. 119-120), after screen out of the proppants, fluid circulation may be injected through the concentric passageway and returned through a bore selector one-way valve (84) to lift the proppants and to allow downward movement of the bore selector with, for example, coiled tubing, until aligning the guiding surface (87) of the bore selector (47A) with the orifices (59) just below the radial passageway (75), to allow a larger volume of circulated fluid between member passageways (24, 25) to clear the proppant screened out. After which, the bore selector (47A) can be aligned with the next radial passageway and the process can be repeated. One possible arrangement is a bottom up-staged operation of circulating through coiled tubing, that can be engaged to the bore selector receptacles (45B of FIG. 118), with a fluid that is injected down the concentric passageway (24), turning at the first open orifices in the innermost passageway (25) below the coiled tubing string sealing engagement with the bore selector receptacle (45B). Other possible arrangements include, for example, jointed tubing which can be used with pressure control at the surface, comprising, for example, a rotating head.

(191) Referring now to FIG. 123, a diagrammatic elevation cross-sectional view of a manifold string (76L) embodiment, usable for a plurality of wells and well types, is shown. The Figure depicts a single conduit string member (51), on the right, placed with a managed pressure string to form a single injection and/or production concentric conduit (2) string member within the passageway through subterranean strata, engaged to a junction of wells (51A) and further engagable to a manifold string (70) member with chamber junction crossovers (21), straddles (22) and plugs (25A) for forming the manifold string (76L) fluidly communicating between the subterranean proximal regions (below 1Y, 1W, 1V, 1U, 1T) and a wellhead (not shown), at the upper end of the single main bore (6). Concentric conduit string members (50, 51) can be installed with a managed pressure conduit assembly member, for becoming the inner (2) and (2A) outer concentric conduits, respectively, after forming the well, dependent upon the application and removal of the inner string (50).

(192) Applicable well types can include substantially hydrocarbon and/or substantially water wells, for example, a right-hand produced hydrocarbon well can crossover to (33) the concentric passageway (24) of the left well, wherein produced (34) fluids are injected (31) downward in the left well to exit the end or enter a chamber junction crossover (21), with plugs (25A) above and below for directing flow into the first annular space (55), contained by a cavern wall (1A) or a passageway through subterranean strata (52) of strata. The hydrocarbon fluid mixture can be separated into gas, liquid hydrocarbon, water and/or solids. If water is produced, it can be used to solution mine the cavern walls (1A), wherein the straddles (22) and plugs (25A) can be rearranged to remove the resulting brine. The manifold string can be usable for production (34), taken through the concentric passageway (24) by an exit bore conduit from the first annular passageway (55) into (35) the innermost bore where it is produced upward. A substantially gas fluid mixture may be taken from the uppermost chamber junction manifold crossover (21), or varying specific gravity fluids of substantially gas or liquid hydrocarbon and/or water may be taken from other chamber junction manifold crossovers (21), between proximal regions (1T, 1U, 1V, 1W, 1Y) through rearrangement of flow controlling device members (22, 25A).

(193) Still other applicable well types include, for example, substantially hydrocarbon wells where chamber junction manifold crossover members (21) can be usable to perform multi-stage fracture propagation operations to create fractures (18A) within proximal regions (1T, 1U, 1V, 1W, 1Y), wherein pressures can be transmitted (28A) to the point of fracture propagation, and wherein proppants can be used to keep fractures open to flow, for example, gas from shale gas deposits or a fluid mixture from low permeability sandstone reservoirs, and whereby the right well may access other deposits, reservoirs or act as a disposal well for produced water.

(194) Other applicable well types include, for example, substantially water geothermal or waste disposal wells, for example, removing the plug (25A) from the junction of wells (51A) and installing a straddle to: allow injection of water into the right well produced through a geothermal reservoir fracture (18A) of the left well that can be selectively controlled by chamber junction manifold crossover (21) members which are accessing select proximal regions (1T, 1U, 1V, 1W, 1Y) or injection of waste fluids produced from the right well into vertically separated proximal regions (1T, 1U, 1V, 1W, 1Y) of the left Well.

(195) Still other applicable well types include, for example, combinations of substantially hydrocarbon and substantially water wells producing high-temperature and pressure water from the right well or feeding water to a geothermal reservoir on the right well and producing steam, further directed to heat tar sands or cold viscous arctic reservoirs on the left side, which can be selectively accessed through chamber junction manifold crossover (21) members to place the heated water in one or more of the proximal regions (1T, 1U, 1V, 1W, 1Y) to produce heated hydrocarbons from one or more of the remaining proximal regions.

(196) Embodiments of the present invention, thereby, provide a member set of combinable systems, apparatus and methods that enable any configuration or orientation of selectively controlled separate simultaneously flowing fluid mixture streams, of varying velocities, within one or more subterranean wells, that can extend from a single main bore and wellhead, to urge substantially hydrocarbon or substantially water fluid mixtures of liquids, gases, solids, or combinations thereof, to or from at least one proximal region, of at least one passageway through subterranean strata, to at least one more proximal region or to said wellhead, at the upper-end of said subterranean well, wherein fluid mixture flow streams may be injected or extracted.

(197) While various embodiments of the present invention have been described with emphasis, it should be understood that within the scope of the appended claims, the present invention might be practiced other than as specifically described herein.