Note : Les descriptions sont présentées dans la langue officielle dans laquelle elles ont été soumises.
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APPLICATION FOR PATENT
INVENTOR:
BRUCE A. TUNGET
TITLE:
PRESSURE CONTROLLED WELL CONSTRUCTION AND OPERATION
SYSTEMS AND METHODS USABLE FOR HYDROCARBON OPERATIONS,
STORAGE AND SOLUTION MINING
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PRESSURE CONTROLLED WELL CONSTRUCTION AND OPERATION
SYSTEMS AND METHODS USABLE FOR HYDROCARBON OPERATIONS,
STORAGE AND SOLUTION MINING
FIELD
[0002] The present
invention relates, generally, to manifold crossover member
apparatus and methods usable for providing pressure containment and control
when constructing and/or operating a manifold string, and during hydrocarbon
operations, storage and/or solution mining, with at least two conduits and
fluid
separated passageways through the subterranean strata, for one or more
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substantially hydrocarbon and/or substantially water wells, or storage
caverns,
that originate from a single main bore and can extend into one or more
subterranean regions.
BACKGROUND
[0003]
Conventional methods for constructing and performing operations on multiple
wells, within a region, require numerous bores and conduits coupled with
associated valve trees, wellheads, and other equipment for injection and/or
production from each well, located within the region. The costs of the
equipment for the construction, control and operation of these multiple wells
can
be extremely expensive, which, historically, has prevented development of
reserves in the oil and gas industry. In addition, obtaining optimal
production
from each of these multiple wells can be a problem because each underground
formation, has its own unique reservoir characteristics, including pressure,
temperature, viscosity, permeability, and other characteristics that generally
require specific and differing choke pressures, flow rates, stimulation means,
etc. for overall production of wells in the region.
[0004] An
embodiment of the present invention can include providing a manifold
string, with a plurality of conduits forming a plurality of pressure barriers
with
at least one intermediate passageway or annular space, that can be usable to
control pressurized, subterranean, fluid-mixture, flow streams, which can be
controlled by the manifold string within passageways through subterranean
strata
for one or more subterranean wells, that can extend from a single main bore.
Important uses of this aspect include, for example, constructing and/or
operation of
one or more subterranean wells from a single surface location, providing the
opportunity for simultaneous well activities and/or common batch activities to
be
performed on a plurality of wells, without the need to remove established
barriers,
reposition a rig, and/or to re-establish barriers necessary for well control.
[0005] An
additional embodiment of the present invention includes one or more
manifold crossover apparatus, usable with a manifold string to selectively
control an innermost and at least one intermediate concentric or annular
passageway. The innermost passageway can be usable for communicating flow-
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controlling devices for engagement in one or more receptacles of a manifold
string to provide, for example, the ability to selectively change controlling
mechanisms and/or flow paths of subterranean pressurized fluids.
[0006] Another
embodiment of the present invention enables fluid separation within a
plurality of radial passageways that can communicate through orifices within
the
innermost passageway, with the radial passageways' diverting walls located
within annular or concentric passageways, to direct fluid flow to the
innermost
passageway. Placing
fluid controlling devices through the innermost
passageway, for engagement within the manifold string, provides further
control
of fluid-mixture flow streams between passageways of the manifold crossover
and the radially inward or radially outward disposed passageways, including
the
passageway surrounding the manifold string to, for example, enable the
crossover of flow between the innermost and concentric passageways. This
crossover of flow enables selective control of the flow in the concentric
passageway by use of valves, which can be engaged to the innermost
passageway for providing selective pressure control of one or more annular or
concentric passageways, while retaining the ability to access wells through
the
innermost passageway.
[0007] In another
embodiment of the present invention, conventional flow controlling
devices are conveyable through the innermost passageway, for engagement
within a receptacle or conduits of a manifold string, to selectively control
fluid
communication by diverting at least a portion of the fluid-mixture flow
streams.
An example of this embodiment includes the placement of a fluid motor and
fluid pump, usable with gas expansion from an underground storage cavern for
driving an impellor to pump and inject water for solution mining, during
combined operations. An additional example includes, placement of an orifice
piston, which can be usable with coiled tubing for under-balanced drilling.
[0008] In a
related embodiment, flow control devices engagable within a manifold
string, a manifold string receptacle, or a plurality of innermost passageway
subterranean valves can be usable with one or more manifold crossovers to
selectively control pressurized fluid, that can be communicated through the
innermost passageway and/or one or more concentric passageways. The flow
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control devices can be used, for example, to replace traditionally unreliable
annulus safety valves with more reliable tubing retrievable valves or, for
example, to repair a failed tubing retrievable safety valve for controlling a
concentric passageway of an underground storage, within depleted reservoirs or
salt caverns, with an insert safety valve placed through the innermost
passageway.
[0009] Another
embodiment of the present invention enables the ability to divert all or
a portion of a fluid-mixture flow stream to a another passageway, that can be
disposed radially inward or radially outward for the purposes of carrying out
simultaneous well construction, well production and/or well injection
operations. The simultaneous well construction and/or well operations enables,
for example, one or more under-balanced coiled tubing fish-bone sidetracks of
a
well to be performed more readily, while producing the well to reduce skin
damage in a low permeability reservoir, or can further enable underground
storage and solution mining operations to be performed simultaneously, thus
removing the conventional requirement for a plurality of rig operations and/or
high risk snubbing operations to strip out a dewatering string from a gas
storage
cavern.
[00010] Another
embodiment of the present invention provides selective control for
placing well construction fluid mixtures of gases, liquids and/or solids
within a
region of the passageway through subterranean strata, while removing
pressurized subterranean fluids from the subterranean strata by over-balancing
or under-balancing hydrostatic pressures, for example, during proppant frac
stimulations, gravel packs and simultaneous underground storage and solution
mining operations.
[00011] In still
another embodiment, the present invention provides an orifice piston
apparatus that can be engagable to a manifold crossover and through which
cables or conduits may pass during, for example, under-balanced perforating or
drilling operations. Engagement, placement and/or removal of the piston can be
assisted by differential pressure applied to the face of the piston during
simultaneous well construction, injection operations and/or production
operations, including for example, performing a mechanical integrity test
using
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a cable, passed through the orifice piston, to measure a gas liquid interface
below the final cemented casing shoe of an underground storage cavern.
[00012] Another
embodiment of the present invention includes the ability to commingle
fluid mixture flow streams and/or to separate selected fluid mixture flow
streams
with an adapted chamber junction. The fluid flow from exit bore conduits can
be commingled through the chamber or directed to intermediate concentric
passageways disposed radially inward or outward of the chamber. The bore
selector can be usable to communicate fluid and/or fluid control devices
through
the innermost passageway and chamber junction for selectively controlling one
or more wells below a single main bore.
[00013] Another
embodiment of the present invention provides adapted chamber
junctions, usable within a single well passageway with a plurality of flow
streams, wherein the innermost passageway of a chamber junction exit bore can
be axially aligned with the innermost passageway of the chamber and the
conduits axially above. At least one more exit bore conduit can contain a
radial
passageway that can be usable with a bore selector, fluid diverter, straddle,
or
other flow control device to fluidly communicate between the innermost
passageway and the surrounding passageway, or another concentric intermediate
passageway.
[00014] Another
embodiment of the present invention, includes a reduced length
manifold crossover with a plurality of radial passageways for communicating
from the innermost passageway to the passageway surrounding the manifold
string, or a radially outward concentric passageway using radially disposed
small conduits, such that flow through the one or more intermediate concentric
passageways effectively travels around and past the rounded shapes of the
small
conduits. In this embodiment, reduced length conventional flow controlling
apparatus can be usable to selectively control flow through orifice
connections
with the innermost passageway to, for example, provide gradual axial
adjustments of solution mining fresh water placement during the salt
dissolution
and/or storage process.
[00015] Embodiments
of the present invention include methods for selectively
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controlling pressures, volumes and temperatures of fluids that can be stored
and
retrieved from a storage space. Examples of such methods include controlled
pressurization of a storage cavern, using water or brine, during gas
extraction to
reduce or minimize the temperature reduction caused by retrieving compressed
stored gas through expansion, thus providing a longer withdrawal period before
reaching a minimum operating temperature for associated well equipment.
[00016] Other
embodiments of the present invention include methods for selectively
controlling a substantially water interface during solution mining and/or
during
re-filling of a cavern, for stored fluid extraction. These selective control
methods affect the shape of the cavern walls to, in use, control working
storage
volumes and solution mining rates for varying storage volume turnovers and
natural salt creep rates, usable for simultaneous underground hydrocarbon
storage and solution mining operations over a number of years, and/or seasonal
storage volume turn-overs.
[00017] Embodiments
of the present invention can include methods for providing a
subterranean brine reservoir with a stored product cushion for selectively
controlling working volume and displacement of liquids or compressed gases to
and from salt caverns, fluidly associated with brine reservoirs holding
subterranean heated brine or generating displacement brine that can be fluidly
communicated in u-tube like conduit, pumping and/or compression
arrangements between caverns.
[00018] In related
embodiments, the present invention can provide methods for
removing salt gas storage cavern sunk construction cost by displacing
conventionally irretrievable cushion gas cavern structural support inventories
for
preventing salt creep with brine from brine reservoirs during high demand,
followed by gas refilling and brine displacement during periods of higher gas
availability to, for example, improve the economic viability of constructing
large scale salt cavern gas storage facilities, as compared to conventional
depleted permeable sandstone reservoir storage.
[00019] In other
embodiments, the present invention can provide methods usable to
selectively access and fluidly communicate between a plurality of specific
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gravity separated fluids, that can be disposed in caverns and subterranean
brine
reservoirs connected with u-tube like conduit, pumping and/or compression
arrangements engaged with manifold crossovers disposed with the caverns.
[00020] Still other
embodiments of the present invention can provide methods usable to
space salt storage caverns and brine reservoirs for salt pillar support within
ocean environments, with pipeline or shipping access and an abundance of water
and brine absorption capacity usable, for example, to access stored specific
gravity separated liquid products above brine with boats and/or pipelines,
while
performing u-tube fluid communication with gas storage caverns to, for
example, perform storage operations during periods of contrary demand
between liquids and gas.
[00021] Finally,
other embodiments of the present invention provide methods for the use
of a fluid buffer for transportation pipelines and/or the selective access to
fluids
of differing specific gravity for use or disposal, for example, pigging
pipelines
of water and other fluids into a storage cavern, wherein the fluids are
selectively
accessed by a manifold crossover with specific gravity cavern separation of
stored hydrocarbons from water/brine for environmentally safe ocean discharge.
[00022] Periodic
catastrophic well failures within the well construction and operations
industry continue to demonstrate the need for a plurality of conventional,
high-
strength, metallic conduit, pressure barriers with intermediate concentric
passageways, that can be usable for monitoring annuli pressures that are
associated with such pressure barriers, particularly as ever deeper and
adverse
geological reservoirs are targeted and/or more gas storage is required to meet
increasing global hydrocarbon demand.
[00023] The
practical need for improved methods and apparatus usable to more
effectively contain subterranean pressures during well construction and
production activities is increased by such activities being performed in the
ever
deeper and higher pressure subterranean regions, which are targeted for their
highly productive rates. In addition, the ever increasing demand for under-
balanced operations to reduce reservoir skin damage, or the increased need for
large underground gas storage facilities placed under or around urban or
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environmentally sensitive areas, increase the need for such improved methods
and apparatus.
[00024] Therefore,
a practical need exists for apparatus and methods usable for placing a
plurality of tubing-conveyed subterranean valves, to contain well pressures,
for
an associated plurality of passageways to pressurized subterranean regions. In
addition, methods and apparatus usable to replace traditionally unreliable
annular safety valves are needed, while retaining access to the innermost
passageways of associated strings for measuring, monitoring and maintaining
the lower end of a subterranean well, including, for example, engaging
replacement insert valves and/or other flow control devices usable to
construct
passageways and control fluid communication and/or pressures within a well.
[00025] With the
imminent approach of peak liquid hydrocarbon production worldwide,
a need exists for lowering the risks and associated costs of developing
remaining
hydrocarbons. In particular, improved methods and apparatus for underground
hydrocarbon gas storage, usable to replace various areas of liquid hydrocarbon
and/or coal consumption, and shorten the timeframe for increased rates of
return
by, for example, enabling simultaneous construction and operation of
underground storage wells with a more cost effective single rig visit and,
thus,
shortening the timeframe for return on inventement while lowering cost by
removing the conventional need for subsequent well interventions by large
hoisting capacity rigs and/or the conventional need for potentially hazardous
and
expensive snubbing operations to remove dewatering strings from explosive
hydrocarbon gas filled storage caverns.
[00026] With the
size and productivity of conventional hydrocarbon discoveries
decreasing, a need exists for methods and apparatus usable to reduce skin
damage in low permeability reservoirs, where conventional methods cause
permanent productivity loss.
[00027] A need
exists for systems and methods for reducing underground cavern
construction costs and for retaining innermost bore access, usable for sonar
measurements taken from inside and/or outside a leaching string to provide
information for better adjusting simultaneous underground storage and solution
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mining operations. These cost-effective systems and methods must be operable
during combined solution mining and storage, especially when encountering
unexpected geologic salt deposit features because stored product may prevent
large hoisting capacity rig interventions during solution mining
conventionally
necessary to remove a completion to take a sonar measurement and/or to adjust
the depth of the outer leaching string, that controls the depth at which a
substantially water interface is placed within a salt dissolution zone.
[00028] A need
exists for systems and methods for providing improved, cost-effective
construction and operation of underground gas storage, particularly within a
depleted reservoir sealed by a subterranean cap rock within a dip closure or
geologic trapping features, wherein the risk of skin damage to the reservoir's
permeability during, or subsequent to, injecting and storing gas results in
the
need for improved, cost-effective, low skin damage construction and operation.
A need exists for systems and methods for providing improved, cost-effective
and higher-efficiency permeability retention under-balanced well construction
and/or completion operations in, for example, depleted gas storage reservoirs
or
valved dual conduit completions in gas tight salt cavern reservoirs to, for
example, increase working storage volume associated with decreases in required
cushion gas volumes required to maintain cavern stability, including the
ability
to cost-effectively empty a gas storage cavern for seasonal demand
requirements.
[00029] In
analogous well operations, a need exists for valved concentric dual conduit
apparatuses and methods usable from a single bore wellhead and valve tree for
pressure containment while water flood stimulating of a hydrocarbon reservoir
through a single main bore, while producing through the same single main bore
for reduced construction cost economic extraction in, for example, instances
of
insufficient nature economic hydrocarbon flow rate pressures.
[00030] With the
use of valved dual conduits, a further need exists for storing products
in a cushion during simultaneous solution mining and storage operations of
brine and storage reservoirs, usable to selectively control working volume and
displacement of liquids or compressed gases to and from other salt cavern
brine
and storage reservoirs, where brine may be subterranean heated and stored or
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generated during displacement operations through u-tube conduit arrangements
between two or more brine and storage reservoirs with fluid pumping and/or
compression to, for example, remove the need for cavern stability cushion gas.
[00031] With peak hydrocarbon production and the associated changes in
consumer
demands, a need exists for contra-seasonal storage of gas and liquid
hydrocarbons in the same brine and storage reservoir caverns, with selective
access to the plurality of specific gravity separated fluids that can be
disposed
within the reservoirs.
[00032] A related economic need exists for reducing salt gas storage cavern
sunk
construction cost by displacing conventionally irretrievable cushion gas
cavern
structural support inventories, during high demand periods, with gas refilling
and brine displacement during lower demand periods, improving economic
viability of larger scale storage facilities.
[00033] A related operational need exists for large scale storage facility
cavern brine and
storage reservoir salt pillar support within an open ocean environment with
more
flexible fluid communication with pipelines, ships and an abundance of water
and brine absorption capacity.
[00034] With exploration, transportation and storage of hydrocarbons
entering ever more
challenging environmentally sensitive and potentially hostile areas, such as
the
oceans or arctic climates, a need exists for methods and apparatus of smaller
foot prints usable to provide a plurality of pressure containing barriers,
wherein
annuli and passageways between pressure barriers are selectively controllable
during well construction and/or well operations, including for example,
production during underbalanced perforating and drilling within low
permeability reservoirs, production during underbalanced gravel packs within
unconsolidated reservoirs, and/or simultaneous gas storage and solution mining
for day trading, transportation pipeline buffer storage, and/or pigging in an
offshore environment.
[00035] Embodiments of the present invention address these needs.
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SUMMARY
[00036] The present
invention relates, generally, to manifold crossover member
apparatus, systems, and methods usable for providing pressure containment and
control when constructing and/or operating a manifold string, and during
hydrocarbon operations, storage and/or solution mining operations, with at
least
two conduits and fluid separated passageways through the subterranean strata,
for one or more substantially hydrocarbon and/or substantially water wells, or
cavern brine and storage reservoirs, that originate from a single main bore
and
can extend into one or more subterranean regions.
[00037] Embodiments
of the present invention can include apparatus (23C of Figures 6,
17-20 and 22-26; 23F of Figures 3, 6, 9-12, 21-26 and 30-31; 231 of Figures 31-
34; 23T of Figures 6, 11-12, 31 and 54-58; 23Z of Figure 38; 23S of Figures
10,
and 42-44; and 23V of Figures 71-73) and methods (CS1 to CS8 and CO1 to
C07 of Figures 3, 5-6, 9-14, 59-62, 66-71 and 81, 1S of Figures 9-10, 12-14,
75-76 and 80-83, 1T of Figures 76-77 and 80-83, and 157 of Figures 82-83),
that
can be usable with a manifold string (70 of Figures 3, 9-11, 30-31, 38 and 80)
or
a plurality of wells manifold string (76 of Figures 6, 11-12 and 54-58), with
one
or more fluidly communicating manifold crossovers (23) forming a subterranean
manifold string. The subterranean manifold string can comprise an upper end
plurality of concentric conduits (2, 2A, 2B of Figures 17, 21, 31-32, 38, 42
and
71-73, 2C of Figures 32 and 71-73, 2D of Figures 71, 39), that can be
engagable
to a valve tree (10 and 10A of Figures 1, 3, 6-10, 13-14 and 80-81) and usable
with selectively controllable surface valves (64 of Figures 1, 3, 6-10, 13-14
and
80-81), and a lower end plurality of conduits (2, 2A, 2B, 2C, 2D, 39), that
can
be arranged (CS! to CS7 of Figures 3, 5-6 and 9-12), configured (CS8 of
Figures 59-62 and 66-71) and/or assembled (146 of Figures 59 and 62, 1S, 1T
157) for fluidly communicating with one or more subterranean regions through
an innermost passageway (25), that can be usable for communicating fluid
mixtures and flow control devices (61 of Figures 9-12, 15, 22-31, 35-36, 39-
41,
43-44, 51-53, 55-58 and 63-65), engagable within a bore or with a receptacle
(45 of Fig. 18) disposed between radial passageway (75 of Figures 18-19, 22-
26,
33-34, 38, 43-44, 54-57 and 71-73), and/or orifices (59 of Figures 18-19, 22-
26,
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33-34, 43-44 and 55-58), which can fluidly communicate between said
innermost passageway (25) and a concentrically disposed passageway (24, 24A,
24B, 24X, 24Y, 24Z, 55). A wall of a manifold crossover and/or a selectively
placed fluid control device can be used to divert fluid-mixture flow streams
of
gases, liquids and/or solids. The flow streams can be diverted from one
passageway to another radially disposed inward or outward passageway. The
diversion of the flow streams serves to, in use, selectively control
pressurized
fluid communication through a plurality of concentric conduits and passageways
through subterranean strata, which can extend axially downward from one or
more wells from a single main bore (6), with a plurality of pressure barriers
(7,
10, 10A, 61, 64, 74, 148, 149) to perform pressurized fluid well construction,
injection, and/or production operations (C01 to C07 of Figures 3, 6 and 9-14),
either individually or simultaneously.
[00038] Embodiments
of the present invention can further inlcude methods that can be
usable with a manifold string (70 of Figures 3, 9-11, 30-31 and 38) or a
plurality
of wells manifold string (76 of Figures 6, 11-12 and 54-58) and/or
conventional
well designs (for example Figures 1, 4, 7-8 and 13-14) for pressure-contained,
simultaneous, underground, hydrocarbon storage and solution mining operations
(1S of Figures 9-10, 12-14, 75-76 and 80-83). The method steps can inlcude
providing two or more conduit strings (2, 2A, 2B of Figures 17, 21, 31-32, 38,
42 and 71-73; 2C of Figures 32 and 71-73; 2D of Figures 71, 39) that can be
engagable to one or more wellheads (7) and valve trees (10 and 10A of Figures
1, 3, 6-10 and 13-14) for selectively communicating fluid mixtures of gases,
liquids and/or solids into, and from, at least one region at the lower end of
a
passageway through subterranean strata, within a salt deposit (5), that can be
usable for storing hydrocarbons and salt dissolution. The method steps can
further include providing water, salt-inert fluids, and/or hydrocarbons within
the
region to form a cushion between the final cemented casing (3) shoe (16) and a
substantially water interface, usable to form a storage cushion space and
further
usable with said two or more conduit strings to provide a plurality of
barriers (7,
10, 10A, 61, 64, 74, 148, 149) for pressure contained underground hydrocarbon
operations (C01-0O2), storage (IS, 1T) and/or to and from a storage cushion
space, during further solution mining operations (1S, 1T and CO1 to C07).
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[00039] Embodiments of the present invention can use a manifold string (70Q
of Figure
3, 70R of Figure 9, 70T of Figure 10, 70U of Figure 30, 70W of Figure 31, 70G
of Figure 38, 76M of Figure 6, 76N of Figures 11-12, 76H of Figures 54-58)
with one or more manifold crossovers (23 of Figures 3, 6, 9-12, 17-26, 30-34,
38, 42-44, 54-58,71-73 and 80), that can be usable with one or more flow
controlling devices (61 of Figures 9-12, 15, 22-31, 35-36, 39-41, 43-44, 51-
53,
55-58 and 63-65) to selectively control pressurized subterranean fluid-mixture
flow streams within a passageway through subterranean strata (52), for one or
more subterranean wells extending from a single main bore (6).
[00040] Various simultaneous underground storage and solution mining
preferred
method embodiments (C06 of Figures 14 and 81, and C07 of Figures 13 and
81) of the present invention can be usable with conventional wells of two or
more string construction, which are capable of containing a pressurized
storage
cushion (1S) while injecting water to displace storage and/or solution mine a
cavern wall (1A).
[00041] Preferred embodiments of the present invention can use a manifold
crossover
apparatus (23) with a first plurality of conduits at an upper end (2, 2A, 2B
of
Figures 17, 21, 31-32, 38, 42 and 71-73, 2C of Figures 32 and 71-73, 2D of
Figures 71) and a second plurality of conduits at a lower end, wherein the
first
plurality of conduits can form at least one intermediate concentric passageway
(24, 24A and 24B of Figures 71-73, 24X and 24Y of Figures 17-20, 22-23, 25-
26 and 32-34 and 24Z of Figures 32-34), that can be disposed about an inner
passageway (25), which can be usable for communicating fluids and devices
that can be engagable within the passageway or with at least one receptacle
(45),
wherein engaged fluid control devices (61, 128 of Figures 6, 27-28) can be
usable to selectively control fluid communication.
[00042] Fluid communication between passageways can occur through fluidly
separated
first and at least second radial passageways (75 of Figures 18-19, 22-26, 33-
34,
38, 43-44, 54-57 and 71-73), that can be associated with first and at least
second
radial passageway orifices (59 of Figures 18-19, 22-26, 33-34, 43-44 and 55-
58)
that are connected to the innermost passageway (25). At least one passageway
can be at least partially blocked from fluid communication by a wall across
the
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passageway or by a fluid control device (61) between the manifold crossover
upper end plurality of concentric conduits and the manifold crossover lower
end
plurality of concentric or non-concentric conduits (2, 2A, 2B, 2C, 2D, 39),
comprising a lower end concentric string or lower end chamber junction (43 of
Figures 38, 45-46, 48-50, 54-59, 61, 66-67 and 71-73), respectively.
[00043] Fluid-
mixture flow streams can be diverted from one passageway to another
disposed radially inward or outward passageway from the diverted passageway
of a manifold crossover, located between said upper end plurality of
concentric
conduits and said lower end plurality of conduits to, in use, control
pressurized
fluid communication within the innermost passageway (25), a surrounding
passageway (55), and/or an intermediate (24, 24A, 24B, 24C, 24X, 24Y, 24Z)
passageway, that can be formed by a plurality of concentric conduits within
the
passageway through subterranean strata (52), that can extend axially downward
from one or more wells from a single main bore (6), during well construction
and/or well operations.
[00044] Various
manifold crossover embodiments (23C of Figures 6, 17-20 and 22-26,
23F of Figures 3, 6, 9-12, 21-26 and 30-31 and 231 of Figures 31-34) of the
present invention can fluidly segregate an intermediate concentric passageway,
circumferentially, to form fluidly separate axial passageways (24X, 24Y, 24Z).
The fluidly separate axial passageways can be associated with radial
passageways (75), which are at least partially blocked from fluid
communication
between the upper and lower ends by one or more walls for diverting fluid
through the radial passageway orifices (59), communicating with the innermost
passageway (25), at axially opposite sides of a receptacle (45), usable for
engagement of a flow controlling device (61), wherein blocking the innermost
passageway causes flow streams to crossover between the innermost
passageway and at least one concentric passageway (24, 24A, 24B, 24C, 24X,
24Y, 24Z, 55).
[00045] Embodiments can further include various related manifold crossover
embodiments (23F of Figures 3, 6, 9-12, 21-26 and 30-31; 231 of Figures 31-34;
and 23S, 23T, 23V and 23Z of Figure 31) with subterranean valves (74 of
Figures 1, 3, 6, 8-10, 13-14, 22-26 and 30-31,and 74A, 74B and 74C of Figures
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30 and 31), that can be engaged to an innermost conduit string (2), at the
ends of
the string (2) and between manifold crossovers to selectively control
pressurized
fluid communicated through passageways for forming a valve-controlled
manifold crossover assembly.
[00046] Other
preferred manifold crossover embodiments (231 of Figures 31-34, 23S of
Figures 10, 31 and 42-44, and 23Z of Figures 31 and 38) can use at least one
radial passageway (75) to fluidly communicate between the innermost
passageway and at least one additional concentric passageway (24A, 24B, 24C,
55), that can be formed by a concentric string (2A, 2B, 2C, 2D) and/or
passageway through subterranean strata (52) by passing through at least one
intermediate concentric passageway (24) formed by the plurality of conduits.
[00047] Other
various manifold crossover embodiments (23T of Figures 6, 11-12, 31 and
54-58, 23V of Figures 31 and 71-73, 23Z of Figures 31 and 38) can use fluidly
separated radial passageways (75), comprising associated passageways of exit
bore conduits (39) of a chamber junction (43), that communicate through radial
passageway orifices (44, 59) with the innermost passageway of the upper end
plurality of concentric conduits (2, 2A, 2B, 2C, 2D). At least one additional
radial passageway can fluidly communicate between the innermost passageway
of at least one exit bore conduit and at least one axial passageway (24, 24A,
24B, 24C, 24X, 24Y, 24X, 55), that is formed by extending the upper end
plurality of concentric conduits to surround and/or engage the exit bore
conduit
or a supporting fluid conduit (150 of Figures 68-73), with a bore selector (47
of
Figures 3, 35-37, 47, 51-53, 59 and 63-65, 47A of Figures 35-36 and 39-41)
usable to selectively communicate fluids and fluid control devices through the
innermost passageway of the chamber junction exit bores for engagement with a
receptacle to selectively control fluid communication through and/or between
passageways.
[00048] Various
construction method embodiments (CS1 to CS8 of Figures 3, 5-6, 9-12,
59-62 and 66-71) are usable to provide a plurality of conventional metallic
conduit pressure barriers with intermediate passageways for pressure
monitoring
with, for example, annulus gauges (13 of Figure 1) for measuring pressures
between a secondary barrier (148 of Figures 60-70) and a potential failure of
a
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primary barrier (149 of Figures 60-70).
[00049] In other
manifold crossover embodiments (23T of Figures 6, 11-12, 31 and 54-
58, 23V of Figures 31 and 71-73), chamber junctions can be usable with a
construction method (CS8 of 59-62 and 66-71) to provide a plurality of
conventional sized conduits within a single main bore, which can be further
usable for securing connectors of fluid communicating conduit or solid-
construction, arranged concentrically or radially, within a secondary pressure
bearing conduit, wherein engagement of primary and secondary full-pressure
barrier conduit strings and/or provision of a pressure relief reservoir, such
as
exposed fracturable strata below a casing shoe, can be used to limit pressure
exerted on the secondary pressure bearing conduit, should the primary conduit
fail.
[00050] Manifold
crossover embodiments (23Z of Figures 31 and 38) of the present
invention can use an exit bore conduit (39) innermost passageway (25), that
can
be axially aligned to the chamber (41) axis with an upper end plurality of
concentric conduits extended, to surround the axially aligned exit bore
conduit
with at least one other exit bore conduit, that passes through at least one
intermediate concentric passageway (24, 24A, 24B, 24C, 24X, 24Y, 24Z) to
fluidly communicate with a different intermediate concentric passageway (24,
24A, 24B, 24C, 24X, 24Y, 24Z) or the surrounding passageway (55). A bore
selector (47, 47A) or flow control device (61) can be usable to selectively
control fluid communication through radial passageways formed by the exit
bores. Additional radial passageways and associated orifices can be usable
with
the flow diverter (21 of Figures 9 and 38) manifold crossover (23Z) to
crossover
between the innermost passageway (25) and an adjacent concentric passageway
(24).
[00051] Other
manifold crossover embodiments (23S of Figures 10, 31 and 42-44) can
use fluidly separated radial passageways, with a first radial passageway
comprising a straddle (22 of Figures 35-36, 39-41 and 43-44) bore axially
aligned to the innermost passageway (25) for fluidly separating at least part
of at
least a second radial passageway, that can comprise a conduit passageway
passing through the intermediate concentric passageway (24), between a
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plurality of concentric conduits (2, 2A, 2B, 2C, 2D) to fluidly communicate
between the innermost passageway (25) and a different intermediate concentric
passageway (24, 24A, 24B, 24C, 24X, 24Y, 24Z) or the surrounding
passageway (55). The straddle (22) can be conveyable through the innermost
passageway and engagable with a receptacle to selectively control fluid
communication, by choking at least part of the at least second radial
passageway.
[00052] Various
flow controlling devices (61), including an orifice piston embodiment
(128 of Figures 6, 27-28), can be conveyable through the innermost passageway
(25) with, for example, a wireline rig (4A of Figure 16), for engagement to at
least one receptacle (45). Placement and removal of the flow controlling
devices can be assisted by greater differential pressure applied to an axial
upward or axially downward piston surface, wherein cables or conduits are
passable through at least one orifice (59) of an orifice piston (128), while
using
the piston surface to divert at least a portion of fluid mixture flow streams
to a
passageway other than the innermost passageway.
[00053]
Construction method embodiments (CS1 of Figure 3, CS2 of Figure 5, CS3 of
Figure 6, CS4 of Figure 9, CS5 of Figure 10, CS6 of Figure 11, CS7 of Figure
12 and CS8 of Figures 59-63 and 66-71) can be combinable with hydrocarbon
operations method (C01 of Figure 3, CO2 of Figure 6, CO3 of Figure 9, C04 of
Figure 10, C05 of Figure 12) embodiments, for using at least one manifold
crossover apparatus (23C, 231, 23S, 23T, 23V, 23Z) to form a manifold string,
or with two or more conduit string pressure-controllable conventional wells
(C06 of Figure 14, C07 of Figure 13) for selectively controlling pressurized
subterranean fluid-mixture flow streams within the passageway through
subterranean strata (52), for one or more subterranean wells extending from a
single main bore (6).
[00054] Embodiments
of the construction and operation methods (CS1-CS8 and C01-
C05), respectively, can include at least one manifold string (70, 76) with a
plurality of concentric conduits (2, 2A, 2B, 2C, 2D) for engaging with an
associated plurality of manifold crossover conduits, with at least one
intermediate concentric passageway (24) disposed about an innermost
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passageway (25) that can be usable for communicating fluids and devices, with
= at least one receptacle (45) usable for engaging fluid control devices
(61) to
selectively control pressurized fluid communication,
[00055] The method embodiments (CS1-CS8 and C01-005) can be usable for
communicating fluid-mixture flow streams through manifold crossover (23)
fluidly separated radial passageways (75) and associated orifices (59) to the
innermost passageways (25).
[00056] Method embodiments (CS1-CS8 and C01-005) can further include diverting
at
least a portion of the communicated fluids-mixture flow streams to a different
passageway that can be disposed radially inward or outward from the diverted
passageway of a manifold crossover (23), between the upper end of a manifold
string or crossover plurality of concentric conduits and the lower end
manifold
string or crossover plurality of conduits to, in use, control pressurized
fluid
communication within the innermost passageway (25), intermediate concentric
passageway (24, 24A, 24B, 24C, 24X, 24Y, 24Z), and/or the surrounding
passageway (55), that can be formed between the plurality of conduits (2, 2A,
2B, 2C, 2D, 39) and the passageway through subterranean strata (52) extending
axially downward from one or more wells from a single main bore (6).
[00057] The method embodiments (CS1-CS8 and C01-007) can also include
providing
subsea or surface valve trees (10, 10A) with subsea or surface valves (64)
and/or
subterranean valves (74), usable with control lines (79 of Figures 1 and 22-
26)
engaged to each of the ends of the innermost conduits (2, 39) of a manifold
crossover (23) to selectively control at least a portion of the pressurized
fluid
that is communicated between the innermost passageways (25) and at least one
concentric passageway (24, 24A, 24B, 24C, 24X, 24Y, 24Z, 55).
[00058] Other method embodiments (CS1-CS8 and C01-007) include providing flow
controlling devices (61), that can be communicated through the innermost
passageway (25) and engaged within a bore (25) and/or receptacle (45) of a
conduit string to selectively control fluid communication, by diverting at
least a
portion of the communicated fluid mixture flow streams.
[00059] Other
method embodiments (CS1-CS8 and C01-005) include providing an
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orifice piston (128) flow-controlling device (61), placeable and removable
from
a bore (25) or a receptacle (45) of a manifold string (70, 76) by greater
differential pressure applied to an axially upward or axially downward piston
surface, wherein cables (11 of Figure 15) or conduits can be placeable through
the orifice piston, while diverting at least a portion of the communicated
fluid-
mixture flow streams to a passageway other than the innermost passageway.
[00060] Various method embodiments (1T, CS1-CS8 and C01-007) can be usable for
selectively controlling communication of fluid mixtures of gases, liquids
and/or
solids between the upper ends of a single main bore (6) and a proximal region
of
the passageway through subterranean strata (52) to over-balance, balance, or
under-balance hydrostatic pressures exerted on the proximal region during
fluid
communication.
[00061] Combined operations method embodiments (1S, 1T, CS1-CS8 and C01-007)
include providing salt-inert fluids and/or hydrocarbons, within a subterranean
region, for forming a cushion between the final cemented casing shoe and a
substantially water interface, usable to form a storage cushion space and/or
solution mine using a salt dissolution process.
[00062] Other combined operations method embodiments (CS1-CS8 and C01-007) can
be usable with two or more strings (2, 2A, 2B, 2C, 2D, 39) for selectively
controlling pressurized fluid communication between a valve tree (10, 10A) and
region of the passageway through subterranean strata (52) to selectively
control
a substantially water interface, with a valve tree and salt-inert or
hydrocarbon
fluids, to form a storage cushion space to, in use, simultaneously provide
pressure contained underground hydrocarbon storage operations (1S of Figures
9-10 and 12-14) to and from the storage cushion space during further solution
mining operations (1 of Figures 7, 9-10 and 12-14).
[00063] Various
combined operations method embodiments (1S, 1T, 157, CSI-CS8 and
C01-007) can replace conventional methods (CM1 of Figure 1, CM2 of Figure
4, CM3 of Figure 7 and CM4 of Figure 8), or supplement conventional well
designs (CM5 of Figures 13-14 and 81), with an apparatus and/or methods of
the present invention to selectively control fluid mixture communication to
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or more wells from a single main bore (6).
[00064] Other
various method embodiments (1S, IT, CS1-CS8 and C01-005) can be
usable for controlling pressurized fluid communication of salt-inert or
hydrocarbon fluids, that are stored and retrieved from a cushion with a valve
controlled manifold crossover to selectively control the substantially water
interface for causing salt dissolution, to affect associated working
pressures,
volumes, and temperatures of fluids stored and retrieved from a storage space
and/or the rate of solution mining during combined solution mining and storage
operations.
[00065] Other method embodiments (1T, CS1-CS8 and C01-007) can be usable for
controlling the shape of the cavern walls with a selectively controlled,
substantially water interface, that can result from pressurized fluid
communication to control working storage volumes and solution mining rates
for varying storage volume turnovers and natural salt creep rates, during
underground hydrocarbon storage and solution mining operations (1S).
[00066] Sill other
method embodiments (1 T, 157) provide water to a substantially water
or fluid interface to generate and displace brine, at a lower end of a first
brine
and storage reservoir via a u-tube conduit arrangement, to at least a second
brine
and storage reservoir to minimize salt dissolution in at least the second
brine and
storage reservoir during such operations.
[00067] Other
related method embodiments (1T, 157) provide selective control of
pressurized fluid communication of salt inert or stored fluids, stored and
retrieved from a salt cavern cushion, to affect associated working pressures,
volumes and temperatures of fluids stored and retrieved from a brine and
storage
reservoir and/or working storage volumes, solution mining rates, salt creep
rates,
or combinations thereof, until reaching the maximum effective diameter for
salt
cavern stability after which salt inert fluids are stored.
[00068] Still other
method emodiments (157) comprising arranging and separating one
or more reservoirs to provide salt pillar support according to pressures of
fluids
stored within and effective diameters of said brine and storage reservoirs.
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[00069] Finally, other various method embodiments (IS, 1T, CS I-CS8 and C01-
007)
can be usable for providing an underground fluid buffer for transportation
pipelines, well production, and/or underground storage operations, wherein a
storage cushion space can be further usable for separating fluids of differing
specific gravity and for selectively accessing the separated fluids through a
manifold crossover.
BRIEF DESCRIPTION OF THE DRAWINGS
[00070] Preferred embodiments of the invention are described below by way
of example
only, with reference to the accompanying drawings, in which:
[00071] Figures 1 and 2 depict a subterranean well and the concept of
permeability skin
damage, respectively.
[00072] Figure 3 illustrates an embodiment of the present invention usable
to reduce the
impact of skin damage and/or solution mine a cavern.
[00073] Figure 4 shows a prior art branching multi-well construction using
conventional
expandable metal technology.
[00074] Figures 5 to 6 illustrate an intermediate construction and
completed method step
for plurality of well embodiments of the present invention from a single main
bore, usable for substantially hydrocarbon and/or substantially water wells.
[00075] Figures 7 and 8 show steps in the construction of a solution mining
well and
underground storage space.
[00076] Figures 9 to 14 depict method embodiments for constructing wells
and
underground storage spaces from a single well and/or a plurality of wells
extending from a single main bore.
[00077] Figures 15 to 16 show prior art apparatus usable with the present
invention.
[00078] Figures 17 to 20 illustrate an embodiment of a manifold crossover
of the present
invention.
[00079] Figures 21 to 26 depict a manifold string using a manifold
crossover of the
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present invention.
[00080] Figures 27 to 28
show an orifice piston embodiment of the present invention for
selectively controlling fluid flow streams.
[00081] Figure 29
illustrates a fluid pump apparatus of the present inventor usable to
selectively control fluid flow streams within embodiments of the present
invention.
[00082] Figures 30 and
31 are diagrammatic illustrations of the manifold crossover
embodiments of the present invention.
[00083] Figures 32 to 34
depict a manifold crossover embodiment of the present
invention with additional intermediate concentric passageways.
[00084] Figures 35 to 37
illustrate apparatus of the present inventor usable to selectively
control fluid flow streams within embodiments of the present invention.
[00085] Figure 38
illustrates an embodiment of a manifold crossover of the present
invention adapted from flow diverting strings of the present inventor.
[00086] Figures 39 to 41
show various views of an adapted prior art apparatus usable as
a bore selector with the present invention.
[00087] Figures 42 to 44
illustrate a manifold crossover embodiment of the present
invention usable to reduce the length of a manifold crossover.
[00088] Figures 45 to 53
show various apparatus of the present inventor usable with the
present invention.
[00089] Figures 54 to 58
depict a manifold crossover embodiment of the present
invention formed from an adapted chamber junction of the present inventor.
[00090] Figures 59 to 67
show various apparatus of the present inventor usable with a
construction method of the present invention.
[00091] Figures 68 to 70
illustrate examples of conventionally sized conduit and bore
configurations usable within a single main bore, and which can be usable with
a
construction method of the present invention.
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[00092] Figures 71 to 73 depict an adapted chamber junction manifold
crossover
embodiment of the present invention with additional intermediate concentric
passageways of a single main bore extended as supporting fluid passageways.
[00093] Figure 74 diagrammatically depicts a subterranean liquid storage
using brine
displacement from a brine pond.
[00094] Figure 75 diagrammatically illustrates an embodiment with u-tube
like fluid
communication between an underground storage cavern and associated
subterranean brine reservoir.
[00095] Figure 76 diagrammatically shows an embodiment with pumping,
turbine or
compressed fluid communication through surface conduit manifold between an
underground storage cavern and associated subterranean brine reservoir.
[00096] Figures 77 and 78 depict graphs for the conventional concepts of
working
volume relationships to subterranean reheating of a gas storage cavern,
subsequent to solution mining and demand usage cycles.
[00097] Figure 79 diagrammatically shows a gas storage cavern dewatering
string
through a completion, prior to its removal.
[00098] Figure 80 diagrammatically depicts a method embodiment usable with
a
underground storage cavern engaged with apparatus and methods to operate
underground storage caverns with brine reservoirs of the present invention.
[00099] Figure 81 diagrammatically depicts a method embodiment using dual
well
underground storage arrangements.
[000100] Figures 82 and 83 diagrammatically depict plan view method
embodiments of
cavern arrangements, usable for operating underground storage caverns and
brine reservoirs.
[000101] Embodiments of the present invention are described below with
reference to the
listed Figures.
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DETAILED DESCRIPTION OF THE EMBODIMENTS
[000102] 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.
[000103] Referring now to Figures 1 to 14, comparisons of the construction
methods CS1,
CS2, CS3, CS4, CS5, CS6 and CS7 of Figures 3, 5, 6, 9, 10, 11 and 12,
respectively, and combined construction and operations methods C01, CO2,
CO3, CO3, C04, C05, C06 and C07 of Figures 3, 6, 9, 10, 12, 14 and 13,
respectively, to the prior art hydrocarbon conventional methods CM!, CM2 and
underground storage conventional methods CM3 and CM4 of Figures 1, 4, 7
and 8, respectively, are shown. Conventional construction methods are
generally not combinable with conventional operations, for various reasons,
including an inability to selectively control operating pressures during well
construction and/or to place a plurality of metallic conduit barriers between
potentially explosive hydrocarbon production and personnel performing the
construction actives.
[000104] Figure 1 depicts an elevation diagrammatic cross-sectional view of a
conventional subterranean well construction method (CM1), usable for various
hydrocarbon or underground storage wells. The Figure depicts a lower
perforated (129) cemented (20) liner (19) portion that can be replaced with a
subterranean storage space of a geologic trap (1A), of a depleted reservoir,
or a
space that was solution mined from the strata bore (17) to salt cavern walls
(1A),
wherein a sliding door (123) is, generally, not present.
[000105] The upper end of the subterranean wells of the present invention can
be
constructible by boring a strata passageway (17) and placing a conductor (14)
casing, that can be secured and sealed to the bore with cement and referred to
as
a casing shoe (16), after which boring, placing and cementing one or more
intermediate casings (15) and sealing casing shoes (16) can occur before
placing
the final cemented (20) casing (3) and casing shoe (16). Chamber junctions and
manifold strings of the present inventor can be usable as, or placeable
through,
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the intermediate casings.
[000106] Generally, boring a final strata passageway (17) through the final
cemented
casing (3) to the targeted subterranean region can be followed by an open hole
completion in, for example, solution mined wells or the depicted cemented (20)
and perforated (129) liner (19) within, for example, hydrocarbon production
wells or waste disposal wells.
[000107] While liners (19) are, generally, engaged to intermediate (15) and/or
final
cemented casing (3) with a hanger and packer (40), non-liner casings (3, 14,
15)
are typically engaged to a wellhead (7), wherein intermediate concentric
passageways or annuli are monitored with gauges (13) for pressure changes,
indicating a breach of the primary barrier (2) or loss of integrity with
secondary
barriers (3, 15, 19), containing released subterranean pressurized fluid.
[000108] Production conduits (2) or tubing generally form the primary barrier,
located
within the passageway through subterranean strata (52) and comprising
passageways of casings (3, 14, 15), liners (19) and strata bores (17). The
production tubing or production casing can be secured to the final cemented
casing (3) or liner with a production packer (40) at its lower end and with
the
upper end secured to the wellhead (7) to form the primary barrier to
subterranean pressurized fluids.
[000109] A valve tree (10) with selectively operatable valves (64) can be
engaged to the
upper end of the wellhead. For conventional solution mined wells, production
and injection conduits (2, 2A) may be free hanging from the valve tree during
the salt dissolution process, as described in Figure 7, after which a
completion,
similar to that shown in Figure 1, may be installed for underground storage
operations.
[000110] The innermost passageway (25) can be controllable by a subterranean
valve
(74), that can be operated with a control line (79) and can be engaged between
conduits of the production (34) or injection conduit string (2), which can be
equipped with a sliding side door (123) to allow limited fluid communication
between the concentric or surrounding passageway (55) and the innermost
passageway (25). The sliding side door can be usable for various construction
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methods, but generally closed for fluid mixture (38) production (34), with the
annular passageway (55) used primarily for monitoring the primary pressure
control barrier (2) and secondary barrier (3) conduit strings.
[000111] In comparison, various apparatus and methods of the present invention
provide a
usable additional intermediate concentric passageway between the innermost
passageway (25) and surrounding passageway (55), and/or provide an outer
string to replace the final cemented casing (3) for installing a completion
with
the final cemented casing string, unlike conventional methods (CM1).
[000112] Convention methods for controlling subterranean pressures with a
completion,
for example 2, 40, 74 and 123, placed within the well bore with a heavy brine
or
drilling mud of greater hydrostatic head to control subterranean pressures of
a
exposed strata bore (17), without a liner (19, 20, 40), are generally secured
with
a production packer (40) that is engaged between the tubing (2) and a final
cemented casing (3), after which the valve tree (10) is installed with the
sliding
side door (123) opened to remove the pressure controlling heavy brine or
drilling mud from the annular space (24), before closing the sliding side door
(123) and flowing (34) fluid mixtures (38).
[000113] In comparison, various methods of the present invention provide a
manifold
crossover that can be usable to selectively control fluid communication during
construction, replacing, for example, the sliding side door (123) for use
during
production and/or injection operations, to provide a selectively controllable
subterranean manifold for controlling one or more wells from a single main
bore
(6), unlike conventional methods (CM1).
[000114] Other conventional methods for pressure control include, for example,
placing a
completion (2, 40, 74), without a sliding side door (123), within a completion
fluid using a liner (19), that is cemented (20) across the strata bore (17),
sealed
with a liner top packer (40), and secured with a hanger to the final cemented
casing (3) to control subterranean pressures, while the valve tree (10) is
placed
to control subterranean pressures. After which, a rig (4A of Figure 16) can be
usable to place perforating guns through the safety valve (74), temporarily
disabling the valve, past a wireline re-entry guide (130) to perforate (129)
the
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passageway through subterranean strata (52) in with an over-balance or limited
underbalance to prevent pushing and tangling perforating guns and the cable
they were placed with, after which the perforating guns and rig are removed in
a
controlled pressure operation.
[000115] In comparison, various apparatus and methods of the present invention
provide a
means of forming a significant under-balance by circulating through an
additional passageway to, for example, perform underbalanced perforating or
drilling through a completion, as later described.
[000116] Maintaining control of subterranean pressures during construction and
subsequent injection, or production to or from the subterranean strata through
well passageways, is a central axiom of well operations that affects virtually
every activity from selection of casings, liners and associated equipment to
the
fluids placed within the passageway through subterranean strata (52) to
hydrostatically hold back fluid mixtures (38) prior to pressure controlled
production (34) through a valve tree (10). In some instances, such as drilling
and well construction activities in low permeability subterranean reservoirs,
long term productivity may be damaged by conventional over-balance methods
of controlling subterranean pressures.
[000117] In lower pressure or lower permeability reservoirs, skin damage (135
of Figure
2) may occur during, for example: drilling of the reservoir, placement of the
completion in an open hole, and/or during conventional methods of over-
balanced perforation, when under-balancing the reservoir risks causing
perforating guns to be pushed upwards and tangling wirelines and/or sticking
the
perforating string and rendering the safety valve (74) and valve tree (10)
inoperable, until the guns and conveyance apparatus are removed from the path
of closing valves.
[000118] Referring now to Figure 2, the Figure depicts a plan view above an
elevation
cross-section with and along line A-A, with dashed lines showing hidden
surfaces, showing the conventional concept of permeability skin damage (135),
with larger reservoir particles (133), such as sand grains in a reservoir,
packed
together by subterranean pressures. Bridging
across particles forms
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intermediate pore spaces (131) within which fluid mixtures of compressed
gases, liquids and smaller solid particles may be contained. When pore spaces
(131) are connected sufficiently to flow fluid mixtures, the connected pore
spaces are permeable (132).
[000119] Fluid mixtures contained within pore spaces (131) are subjected to
the
subterranean overburden pressure with permeability (132) providing a
passageway through which fluid mixtures may migrate, wherein their fluid
connection to deeper subterranean overburden forces pressurizes shallower
permeable (132) pore spaces (131).
[000120] Controlling subterranean pressurized fluid mixtures in permeable pore
spaces,
adjacent to a bore hole (17) or perforation tunnel (129), requires a higher
hydrostatic or dynamic head fluid mixture within the bore (17) or perforation
(129) acting against pore (131) pressure, that can hydraulically force smaller
particles (134) or liquids, for example the particles or liquids in low
permeability gas reservoirs, into the throat of low permeability adjacent pore
spaces (131). However, insufficient pressure and/or surface area can force the
particles or liquids out of the pore spaces (131) during production, thus
causing
skin damage (135). Reservoirs with low permeability or flow capacity through
these skin-like pore spaces (131) can have insufficient pressure and/or flow
area
against the choking particles (134), or capillary forces of the liquid, to
force
intruding fluid mixtures back out of the pore throats, which can result in
permanent skin damage (135) that affects productivity throughout the remaining
well life.
[000121] Figure 3 depicts an elevation diagrammatic view through a cross-
sectional slice
of the subterranean strata of an embodiment of construction (CS1) and
hydrocarbon operations (C01) methods, which include a manifold string (70Q)
of the present inventor. The manifold string (70Q) can be usable with
embodiments of manifold crossovers (23F, 23Z), as shown in Figure 3. In
addition, the Figure shows various conventional well construction elements,
similar to that shown in Figure 1, with a dual spool tree (10A) capable of
flow
through the innermost bore (25), and a concentric passageway (24) engaged to
the wellhead (7) and a completion string (2) that can comprise a manifold
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crossover (23F), with inner (2) and outer (2A) conduit strings engaged to the
final cemented casing (3) and a production packer (40) sealed (66) to the
liner
(19) at its upper end. A production conduit (2), with another manifold
crossover
(23Z) within the surrounding (55) passageway through subterranean strata (52),
can be usable to perform a series of fishbone sidetracks (136), wherein
production packers (40), engaged to the liner (19), separate various producing
zones with the lowermost zone perforated (129).
[000122] The construction (CS1) and hydrocarbon operations (C01) methods
depict a
manifold crossover (23F) that can be usable to provide production and/or
injection through either the innermost (25) or concentric (24) passageways.
The
lower conduit string (2) flow diverting manifold crossovers (23Z) can be
engaged to the liner (17) with the upper packer (40);after which, the upper
assembly (2, 2A, 23F, 40, 66, 137) can be engageable to the lower placed
assembly (2, 2A, 23Z, 23Z, 40, 137), with a conventional connector (137), for
example a ratch-latch, sealed (66) to the liner (19) with, for example a
polished
bore receptacle and mandrel, and secured to the final production casing (3)
with
a production packer (40). Next, the dual spool valve tree (10A) may be placed.
[000123] The construction (CS1) method can be usable for underground storage
within a
geologic trap (1A) of a depleted reservoir through, for example, lower skin
damage side-tracks (136) or perforations (129), or in combination with an
operations method (C01) that can be usable for underground storage and
solution mining of cavern walls (1A) when well trajectories are oriented
vertically, the lower end packer (40) and cementation (20) are omitted from
the
perforated (129) liner (19) to allow fluid flow for salt dissolution. For
brine
and storage reservoir cavern creation, a salt inert cushion fluid, with a
specific
gravity lighter than water, can be forced into the well and allowed to rise
around
the liner (19), where it can be trapped by the liner top packer (40) to form a
water interface that, combined with conventional interface measuring
technology, either placed through the innermost passageway (25) or
permanently attached to various conduits of the manifold string (700J, can be
usable to selectively control combined storage and mining operations, with
alternating injection of a salt inert stored cushion fluid, injection of fresh
water,
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and extraction of brine through the valve controlled manifold crossover (23F)
and flow diverting manifold crossovers (23Z).
[000124] Once pressure containing barriers are placed (CS1) for substantially
hydrocarbon applications, the operations method (C01) of displacing to a
lighter
specific gravity hydrostatic column by circulating a lower density fluid
through
the innermost (25) and concentric (24) passageways, can be usable to under-
balance the hydrostatic head of the fluid within the passageway through
subterranean strata (52), below the pore pressure contained behind the liner
(19).
This will allow fluids to flow outward during perforation (129), thus reducing
or
avoiding skin damage (135 of Figure 2) in non-salt reservoirs, or placing a
cushion under the final cemented casing (3) shoe (16) for brine and storage
reservoirs. A wirline rig (4A of Figure 16) can be engagable to the valve tree
(10A) for placement of guns to perforate (129) the liner in a pressure
controlled
and under-balanced state, without the risk of pushing the guns axially upward
with released pore space fluid, by circulating down the innermost passageway
(25) using a cable passable flow control device (61), for example an orifice
piston (128 of Figures 27-28), that can be engaged in the upper manifold
crossover (23F), and taking returns through the concentric passageway (24) and
through the valve tree for pressure controlled processing. Once perforating
has
been completed in a non-salt reservoir, the lower production packer can be set
to
separate and pressure-contain the lower perforated fluid (38) production (34)
zone.
[000125] Hydrocarbon method embodiment (C01) can be usable to perform
underbalanced drilling operations, while allowing production (38) to be
extracted (34) from a non-salt reservoir, to reduce or avoid skin damage (135
of
Figure 2) with, for example coiled tubing, wherein a series of side tracks
(136),
such as the fish-bone style sidetracks shown in Figure 3, are carried out
through
the exit bores of the manifold crossovers (23Z of Figure 38) using a bore
selector (47 of Figure 37). If a ported bore selector (47 of Figures 51-53)
and
the drilling circulating conduit are passed through an orifice piston (128 of
Figures 27-28), shown as a flow control device (61) in Figure 3, a lighter
specific gravity fluid, such as gas or diesel, can be circulated down the
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concentric passageway (24), through orifices (59) in the inner conduit (2) of
the
upper manifold crossover (23Z), and through the bore selector (47) for mixing
with coiled tubing drilling returns to further under-balance the drilling
operations and associated skin damage (135 of Figure 2).
[000126] Embodiments of construction (CS1) and hydrocarbon operations (C01)
methods
can be usable to under-balance various operations performable through a
completion. For example, gravel packing an unconsolidated reservoir or
underbalanced construction of underground storage in a depleted sandstone
reservoir where skin damage adversely affects storage efficiency. In these
embodiments, the innermost (25) and concentric (24) passageways can be
designed for flow through the valve tree (10A) for underbalanced gravel pack
placement or well construction. In comparison, conventional completions (CM1
of Figure 1) are generally not usable for simultaneous construction and
production operations, and the conventional method of over-balance placement
may permanently damage a reservoir by choking pore throats, thus reducing its
permeability.
[000127] Referring now to Figure 4, an elevation cross-sectional view within
the
subterranean strata of a branching chamber (832) with expandable metal
branches (836, 838) is shown. The Figure illustrates single barriers below the
branch, which comprise expandable metals of lesser strength than traditional
hardened metal materials, wherein a secondary barrier passageway and barrier,
necessary for monitoring the integrity of primary subterranean well barriers
below the junction, is not present.
[000128] The branching chamber (832) is placed within a parent well bore and
flexible
metal branches (836, 838) are expanded to provide a pressure containing
junction, that can be limited by lower expandable metal burst and collapse
pressure ratings in comparison to conventional tempered and/or heat treated
and
hardened metal products.
[000129] In comparison, various apparatus and methods of the present invention
can be,
generally, constructed with conventional, non-expandable metals of higher
strength, with a plurality of barriers and annular passageways below junctions
to
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provide increase pressure bearing capacity and redundancy.
[000130] Figure 4 shows branch wells (801, 808) extending from the branching
chamber,
and a branching sub (612) is shown at a node of a parent well, having parent
casing (604) running through intermediate casing (602) and surface casing
(600)
from a wellhead (610). The need to engage a branching sub (612) for the
production tubing (820) and support of the low collapse strength expandable
metal branching chamber (832) requires cementing the junction in place, thus
preventing construction of a usable annular space to monitor the primary well
barriers of branch wells (801, 808). Cementing conduits within well bores
(801,
808) represents a single barrier that may, should it fail, bypass the
connector
(806), leaking through the strata and/or collapsing the expandable junctions
(836, 838) and leaking between the branch sub (612) and branching chamber
(832) into an annulus, with insufficient hydrostatic column, when placed
within
the shallow strata to prevent breaching the parent casing (604) barrier. This
parent casing (604) barrier can be exposed to higher subterranean pressures
transmitted through a poorly cemented annular space, without prior indications
of increased pressure from, for example, an annulus gauge (13 of Figure 1).
[000131] In comparison, various apparatus and methods of the present invention
can be
usable to place shallow junctions of conventional hardened metal with
concentric passageways or annular spaces, extending axially downward from
wells of a junction of wells, to provide sufficient hydrostatic pressures
and/or
metal strength for a usable secondary barrier. A relief pressure reservoir,
for
example, an exposed fracturable strata bore below a casing shoe in fluid
communication with the annular space, can be usable to provide a secondary
barrier, which can protect the above ground or mud-line environment in the
event of a primary barrier failure.
[000132] Methods of completing the branched well shown in Figure 4 include
providing a
down hole manifold (612) set in the branching chamber (832), above the
junction of the branch well (801, 808) bore lining (805, 810) engagements
(806).
The downhole manifold can be oriented and latched via an apparatus (510, 862)
in the branching chamber (832) by orienting the manifold (612) with a key
(812)
and a slot (860) arrangement. The Figure shows production tubing (820) that
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can extend from the surface to the downhole manifold (612) to isolate the
parent
well from the branch wells (801, 808), which can be closed by plugs placed in
the branch well engagements (806) below the downhole manifold (612).
[000133] If the junction is placed within deeper strata, the expandable metal
branch can
provide sufficient barriers when combined with a larger hydrostatic pressure
head between the tubing (820) and the parent casing (604), similar to a multi-
lateral application placed deep within the subterranean strata or if a
production
packer arrangement is used above or in place of the downhole manifold (612).
However, the collapse resistance of an expandable metal junction may be
insufficient to adequately resist very deep subterranean pore pressures.
[000134] Application of prior art branching technologies are, generally,
limited by the
need to use unconventional expandable metal technology, including the
unconventional need to expand the non-concentric branching chamber (832)
branches (836, 838), cement them in place, and then orient (812, 860) and
latch
(510, 862) an unconventional downhole manifold (612), with no annular
passageways available to monitor well integrity below the chamber (832).
Without the provision of two conduit barriers and an annular passageway of
sufficient hydrostatic head to provide sufficient pressure barrier support and
monitoring time, the application is generally limited to multi-lateral type
applications and access to the innermost bore is necessary.
[000135] In comparison, various apparatus and methods of the present invention
can be
usable with larger diameter conduits of sufficient wall thicknesses and
associated pressure rating for shallow multi-well applications from a single
main
bore. The prefabrication with conventional technology, within a controlled
environment, followed by onsite assembly, placement and/or construction
within a subterranean environment, with the use of conventional off-the-shelf
technologies, can reduce the risk in applications of the present invention.
[000136] Referring now to Figures 5 and 6, the Figures show construction (CS2,
CS3) and
hydrocarbon operations (CO2) method embodiments, illustrating a plurality of
wells, one of which is bored (17) and one of which is yet to be bored (17A),
branching from a junction of wells (51A) within the shallow strata and
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depicting, for example, a plurality of perforated (129) hydrocarbon wells to
non-
salt reservoirs or a plurality of underground storage and solution mining
wells to
brine and storage reservoirs, usable to form and use space within the walls
(1A)
of one or more salt caverns.
[000137] Figure 5 depicts an elevation subterranean cross-sectional
diagrammatic view of
an intermediate construction step (CS2) embodiment using a chamber junction
(43) and bore selector (47). The Figure illustrates a placed conductor casing
(14), that is shown cemented (20) and sealed at the casing shoe (16) after
boring
the surface hole. The Figure further depicts a bore (17) that has been drilled
through the conductor (14) and strata with a placed chamber junction (43), for
example that of Figures 45-46, 48-50 or 61 and 66-57, and cemented (20) to
form a casing shoe (16) of an intermediate (15) casing for a substantially
hydrocarbon well or substantially water disposal well in non-salt reservoirs,
or a
final cemented casing (3) for substantially hydrocarbon and substantially
water
underground brine and storage reservoirs in salt reservoirs. A bore selector
(47),
for example as shown in Figures 47, 51-53 or 63-64, can be engaged within the
chamber (41) at the chamber bottom (42) to selectively access the right hand
chamber junction (43) exit bore conduit (39). The Figure shows a strata bore
(17) that has been drilled to form a passageway through subterranean strata
(52).
A containing conduit, about the exit bores (39), is shown added to the chamber
junctions to form a secondary barrier (2A, 148), similar to those shown in
Figures 48-50, 66-67 and 68-70, disposed about primary barriers (2, 39, 149 of
Figures 68-70), to allow concentric passageways or annular spaces below the
chamber junction (43) to be monitored through various supporting fluid
communication conduits (150 of Figures 66-70).
[000138] For construction of underground brine and storage reservoir cavern
wells usable
to form cavern walls (1A) in a salt deposit, the strata bores (17) may diverge
to
separate caverns before being oriented for vertical solution mining as shown
in
Figure 6, or progress axially downward in a parallel or intersecting
arrangement
as described in Figure 5 with a completion similar to that shown in Figure 11.
[000139] Referring now to Figure 6, the Figure depicts an elevation
diagrammatic view
through a cross-sectional slice of the subterranean strata of a construction
(CS3)
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and combined construction and operations (CO2) method embodiment,
illustrating a manifold string (76M) with a manifold crossover (23F)
embodiment. The Figure shows selective control of the fluid communication
between two separate wells, through a single main bore, using subterranean
valves (74) engaged at both ends of a manifold crossover (23C) for forming a
valve controlled manifold crossover (23F) engaged with a chamber junction
manifold crossover (23T), which can be usable with a flow controlling plug
(25A) to direct flow from left and right wells to the innermost (25) and
intermediate concentric (24) passageway, respectively.
[000140] After boring (CS2 of Figure 5) passageways (17) through the chamber
junction
(43) and strata, liners (19) can be engaged to the primary barrier conduit
(149)
with hangers and liner top packers (40), extending axially downward for a
plurality of wells from a single main bore (6). The hydrocarbon method (CO2)
can be usable to perforate (129) cemented (20) liners (19) in a substantially
hydrocarbon well for production from a reservoir, or storage in a depleted
sandstone reservoir well, or disposal and/or simulation in a substantially
water
well in non-salt reservoirs, or brine and storage reservoirs operations in
salt
deposits.
[000141] For under-balanced perforating and/or when string tension is
necessary, the
method (CO2) can be usable to place a liner hanger, with a bypass flow
capacity
to suspend the tubing (2), with the unset lower end production packer (40) and
upper end connector (137) (e.g. a ratch-latch), for each of the plurality of
wells,
usable to engage the chamber junction manifold (23T) and valve controlled
manifold crossover (23F) placed as a single assembly prior to engagement of a
valve tree (10A). Thereafter, a plug can be placeable within the lower
production packer for setting and placing the lower end conduit strings of the
manifold string (76M) in tension.
[000142] In the perforating example illustrated, a cable rig (4A of Figure 16)
is engagable
to the valve tree (10A) for placement of cable (11 of Figure 16) conveyed by
perforating guns passing through an orifice piston (128), that is shown
engaged
between the valves of the upper manifold crossover (23F) with the perforating
guns selectively communicated through the bore selector (47) and mule shoe
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(130) to perforate (129) the liner (19). An under-balance below the
hydrostatic
pore pressure can be achievable by injecting a low specific gravity fluid (31)
through the lower innermost passageway (25) to prevent upward movement of
the perforating guns, after firing with the fluid that is returned past an
unset
lower packer (40) and through an intermediate concentric passageway (24B),
that can be diverted through a selectively controllable valve manifold
crossover,
similar to that of Figure 31, usable with three flow streams.
[000143] After perforating (129), the bore selector (47) can be removed and
the straddle
(22), within the chamber junction manifold crossover (23T), and the orifice
piston (128), within the other chamber junction (23F), can be replaced with
plugs (25A of Figures 11-12) that can be usable to control fluid mixture (38)
flow streams produced (34) from the left side well with independent production
in the right side well, opposite to the injection arrows shown.
[000144] The hydrocarbon operations method (CO2) can be usable for combined
operations of substantially hydrocarbon and substantially water wells that are
usable for injection (31) and production (34) through a single main bore (6)
to,
for example, water flood the lower portion of a reservoir while producing from
the upper portion of the reservoir through a subsea valve tree. Water can be
injected (31) into the concentric passageway (24) for crossing over at the
manifold crossover (23F) and flowing through the innermost passageway (25) to
the right side perforated (129) liner (19), while production from the left
side
perforated (129) liner (19) can be produced through the concentric passageway
of the chamber junction manifold (23T). This production can cross over to the
innermost passageway (25), at the upper manifold crossover (23F), wherein both
the injection and production fluid mixture streams can be selectively
controlled
by a plurality of barriers (2, 2A, 2B, 3), subterranean valves (74) and a
valve
tree (10A).
[000145] The construction method (CS3) can be usable with surface or subsea
valves
trees (10A), for example, an adapted horizontal subsea tree. An extra spool
can
be added to a conventional valve tree (10 of Figure 1) to allow continuous
flow
through a concentric passageway (24) with storage to and from, for example, a
plurality of depleted reservoir storage wells from a single main bore (6),
with a
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perforated (129) liner. The storage boundary (1A) can be a geologic trap such
as a dip closure or solution mined cavern walls in a salt deposit usable for
containing stored product.
[000146] The construction (CS3) and hydrocarbon operations (CO2) methods are
adaptable for two laterally separated, substantially water, underground,
solution-
mined, storage cavern wells, wherein the cemented (20) liner (19) is replaced
with a free-hanging liner (19) without the lower packer (40), flow diverting
string (similar to 70T of Figure 10 below the cement packer 139), that can be
engaged to each primary barrier (149) exit bore conduit (39) of the chamber
junction (43). An outer string (2A of Figure 10) can be engaged with the
depicted liner hanger and packer (40), with the connector (137) at the upper
end
of the inner string (2 of Figure 10). The arrangement can be engagable to the
manifold crossover (23T) and usable to inject and trap a cushion of salt inert
fluid between the bore (17) and the liner top packer (40) and final cemented
(20)
exit bore (39) casing shoe (16), during solution mining operations by using,
for
example, manifold crossovers (23S of Figure 10) to adjust the water interface
level.
[000147] Fresh water can be injected (31) through the innermost passageways
extending
from the chamber junction manifold crossover (23T), with the straddle (22) in
place and the bore selector (47), to both the left and right side wells,
respectively. Salt saturated brine can be returned (34) from the solution
mined
space within the cavern walls (1A) from both left and right side wells through
a
lower manifold crossover (23T) orifice (59), which is not present in
previously
described embodiments and requires blocking of the surrounding passageway
by, for example, cement and/or a packer. In other embodiments using the radial
passageway covered by the straddle (22), the orifice (59) can be provided with
a
one-way valve, usable to inject and trap a salt inert fluid cushion for
selectively
controlling the water interface during solution milling.
[000148] The method (CS3) can be usable with either substantially hydrocarbon
and/or
substantially water wells, using an inner chamber junction (43), similar to
that of
Figures 45-46, placed and engaged at its lower end with packers (40) to the
outer chamber junction (43) primary barrier (149) exit bore conduits (39).
This
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placement of the inner chamber junction (43) provides a surrounding
passageway (55) for primary barrier monitoring within the hydrocarbon well
with a lower packer (40), or for brine returns in a free-hanging manifold
string
solution mining water well, with an additional intermediate concentric
passageway (24B) for monitoring the secondary barrier (148).
=[000149] Figures 7 and 8 depict elevation subterranean cross-sectional
diagrammatic
views of the generalized conventional construction steps (CM3, CM4) for
forming an underground storage space within salt cavern walls (1A), using a
solution mining salt dissolution process. The Figures illustrate conventional
construction of a storage well, with a conductor (14), an intermediate casing
(15), and a final cemented casing (3) sealed with a casing shoe (16), through
which a strata passageway (17) is bored. The Figure shows passageway through
subterranean strata (52) within which solution mining begins in Figure 7 by
placing a free hanging inner string (2) within an outer free hanging string
(2A),
which may be adjusted with the use of a large hoisting capacity rig during the
processes to reposition the point at which fresh water enters the solution
mining
region of a salt deposit (5) and/or to provide improved sonar measurements
than
are possible through casings (2, 2A), after which the free hanging strings are
removed from the passageway through subterranean strata (52) of Figure 8
showing a completion (2, 40, 74) installed with a dewatering string (138)
preventing valve (74) operation until after the cavern is emptied for gas
operations and the string (138) is snubbed or stripped out of the well.
[000150] Referring now to Figure 7, the Figure depicts the conventional
solution mining
(1) method (CM3) starting with injection of potable water, pond water, ditch
water, sea water, or other forms of water, generally termed fresh water due
its
unsaturated salinity level as compared to extracted salt saturated brine. The
Figure shows the water injected through the innermost passageway (25) and
returned through the intermediate concentric passageway (24), between the
inner (2) and outer (2A) free hanging conduit strings, using direct
circulation
with a cushion, generally comprising diesel or nitrogen. The injected water is
shown forced into an additional intermediate concentric passageway (24A),
between the outer conduit string (2A) and a final cemented casing (3), to
control
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the water interface (117), wherein an initial solution mined space is created
for
insoluble strata to fall through a substantially water fluid stream to the
cavern
floor (1E).
[000151] Generally, once sufficient space is formed with direct circulation, a
conventionally more efficient indirect circulation can be performed by
injecting
(31) down the intermediate concentric passageway (24) with returned (34)
fluids
passing through the innermost passageway (25), with a salt inert fluid fluidly
communicated through a port in the wellhead (7) and trapped in the additional
concentric passageway (24A) to maintain a water interface (117) during
circulation.
[000152] Generally, caverns are solution mined from the bottom up by mining a
space
(1B) with a water interface (117), raising the water interface (117)
repeatedly to
create increasing volumetric spaces (1C and 1D) with water-insoluble strata
falling through fluids, and raising (1E. IF, 1G) the cavern floor while
continuously injecting (31) fresh water and extracting (34) saturated or near
saturated salt brine, that can be dependent upon the residence time, pressure,
volume and temperature conditions of the salt dissolution process.
[000153] As the process of solution mining may take years, dependent upon the
size of
cavern being mined, the rate at which fresh water is injected (31) and the
number of large hoisting capacity rig visits required to construct the well
and
adjust the outer leaching string (2A) during formation of a salt cavern
represents
a significant net present value investment.
[000154] Referring now to Figure 8, the Figure depicts the conventional
completion
method (CM4) following solution mining (CM3 and 1 of Figure 7), wherein the
free hanging leaching strings (2, 2A) have been removed and a completion,
similar to CM1 of Figure 1, comprising a production casing (2) and production
packer (40), engaged to the final cemented casing (3), have been placed and
engaged to the wellhead (7) with a valve tree (10A), that can be engaged to
the
upper end using valves (64) to selectively control injection and extraction of
fluids.
[000155] In liquid storage wells, where the stored products do not pose a
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evaporative or expansion escape risk, for example crude oil or diesel,
generally,
no subterranean valve (74) is present. In addition, a dewatering string (138),
generally, remains in place through the production casing (2), and product is
injected (31) indirectly through the passageway, between the dewatering (138)
and the production casing (2), taking brine returns (34) through the
dewatering
string (138) with stored liquid product displacing brine from the space within
the cavern walls (1A). Retrieval of stored liquid is generally accomplished by
direct injection of brine, from a pond or storage facility, through the
dewatering
string (138) to float the lower specific gravity stored product out of the
cavern as
described in Figure 74.
[000156] In gas or volatile liquid storage instances, a failsafe shut
subterranean valve (74)
is generally placed in the production casing (2), through which a dewatering
string can be placed. Gas or volatile liquids can be stored using indirect
circulation for injection (31) through the passageway, between the dewatering
(138) and production casing (2), and taking brine returns (34) through the
dewatering string (138), after which the dewatering string (138) must be
stripped or snubbed out of the well in a relatively high risk operation, where
personnel are in close proximity to pressurized barriers, to allow the fail
safe
safety valve (74) to function.
[000157] Conventional methods (CM3, CM4) of constructing salt caverns and
initializing
gas or volatile liquid underground storage are labor intensive and potentially
hazardous, taking a number of years to complete before realizing a return on
investment.
[000158] Referring now to Figure 9, an elevation cross-sectional diagrammatic
view
through a slice of subterranean strata along the axis depicting embodiments of
construction (CS4) and hydrocarbon operations (CO3) methods are shown. The
depicted embodiments can be usable with a manifold string (70R) and flow
diverter (21) and a manifold crossover (23F) of the present invention. The
Figure illustrates well construction, similar to Figure 3, above the final
cemented
casing (3), which comprises the outer string (2A) of the manifold string (70R)
cemented (2) to form a casing shoe (16). An initial cavern space, within salt
deposit (5) cavern walls (1A), can be used for storage during solution mining
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(1S). The construction and combined operations methods (CO3-007) can be
usable to reduce both the number of large hoisting capacity rig visits and the
time frame before realizing a return on investment, when compared to
conventional methods (CM3 and CM4 of Figures 7 and 8) with simultaneous
storage and solution mining (15).
[000159] After cementation (20) of the manifold string (70R) and any
associated
mechanical integrity tests of the casing shoe (16), and the placement of a
salt
inert cushion fluid, water can be injected into the solution mined (1) spaces
(1B,
1C, 1D), initially, using an indirect method. The indirect method injects the
water through the intermediate concentric passageway (24), taking returns
through the innermost passageway (25) and orifices (59) in the inner conduit
string (2), at its lower end. Thereafter, a direct method can be used to
inject
water through the innermost passageway (25) to flow diverting crossovers (21),
described in Figure 38, that can be selectively controlled with flow diverting
bore selectors (47A of Figures 35-36), also usable to inject and trap a salt
inert
cushion fluid between the final cemented casing (3) shoe (16) and the water
level (117). After sufficient volume is formed through faster leaching of a
lesser
diameter cavern roof, the water interface (117) can be lowered with the
cushion
between the lesser diameter roof and water interface usable as a storage space
(147) during simultaneous storage and solution mining (15), wherein below the
water interface, the flow diverting bore selectors can be usable to
selectively
place water for solution mining (1) a larger diameter cavern, during which
insoluble strata can fall and accumulate (1E, IF and 1G) at the bottom of the
cavern. Saturated brine can enter orifices (59) in the inner conduit (2) and
can
cross over to the intermediate passageway (24), below the bore selector for
extraction through the valve tree (10A).
[000160] The method (CO3) can be usable to form an initial space within cavern
walls
(1B) by using direct circulation of fresh water through the innermost
passageway (25), with salt saturated brine returned through the concentric
passageway (24) using the lowest water interface (117) above the lower end of
the outer string (2A). Alternatively, the initial space within the cavern
walls
can be formed indirectly from the circulation of water through the concentric
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passageway (24) to the innermost passageway, during which time a salt inert
fluid cushion can be periodically injected through either passageway (24, 25)
and trapped by the casing shoe (16).
[000161] Various initial cavern volume shapes (147) usable for simultaneous
storage and
solution mining (1S) can be formed with direct or indirect circulation and
adjustment of the salt inert fluid cushion that can control the water
interface,
selectively increased with injection or removed with a manifold crossover
(23),
after the initial insoluble volume. While no two caverns are ever the same
shape
after completing solution mining, any conventional design shape is formable
with the present invention, for example those of Figures 10, 13 and 14, can be
usable to more quickly form a cushion storage volume (147 of Figures 13 and
14) and can be further usable as a leaching cushion for subsequent solution
mining operations (1).
[000162] The conventional rule-of-thumb for salt dissolution is that the top
of the cavern
leaches twice as fast as the sides of the cavern, and the sides of a cavern
leach
twice as fast as the bottom of a cavern. Conventional methods (CM4 of Figure
8) of cavern formation involve developing a cavern width, first, at its
deepest
level and, then, working upward to complete the cavern shape, wherein the
present method (CO3) can be usable to form a smaller volume that can be usable
for storage and cushion, after which solution mining of the cavern side walls
(1A) can continue, either conventionally or with method embodiments (1T of
Figures 75-76 and 80-83) for brine and storage reservoirs.
[000163] Liquid storage is generally volume dependent, with a high unit value
per unit of
volume, and salt caverns are generally preferred with liquid storage methods
(1T
of Figures 75-76 and 80-83) of the present invention usable with gas storage.
Gas storage within gas tight salt caverns is generally more profitable for
shorter
trading periods to increase the number of turns, referring to turn-around
volumetric usage as described in Figure 78, wherein only a portion of the
cavern
is used with larger seasonal swings that are conventionally left to less
efficient,
depleted, sandstone reservoirs, presumably due to the higher investment cost
of
the more efficient salt cavern storage space dedicated solely to gas storage.
Various methods (157, C01-007, 1S and 1T of Figures 75-76 and 80-83) are
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usable to to combine both liquid and gas storage.
[000164] The construction method (CS4) manifold crossover (23F) can be usable,
for
example, to perform both solution mining and gas storage operations (IS)
without rig intervention. A smaller cavern volume (147), formed by first
solution mining a smaller diameter cavern axially upward at the faster
dissolution rate of the cavern room, can be usable to form a gas trading
cushion
volume (147). Thereafter, the water interface can be lowered by the volume of
gas stored, during, for example, the weekend lower usage period for displacing
brine, and released during daily peak demands as fresh water is injected to
solution mine the cavern walls (1A) to a larger diameter from the bottom up.
The stored cushion product extraction and associated pressures are aided by
methods of (1T of Figures 75-76 and 80-83) fresh water injection, brine
generation and displacement betwen a u-tube conduit arrangement between
brine and storage reservoirs.
[000165] Figures 13 and 14, depict elevation diagrammatic views of combined
hydrocarbon operations method embodiments (C06 and C07, respectively) that
can be usable with conventional well designs (CM5), including conventional
designs incorporating one or more apparatus of the present invention to
solution
mine various cavern design shapes while simultaneously storing a valued
produced, for example, hydrocarbon gas within the walls (1A) of a salt deposit
cavern. The Figure shows a smaller cavern cushion storage space (147) that can
be solution mined, first, for the purpose of simultaneous storage operations
(1S)
during solution mining operations (1) with a working pressure (WP), usable to
selectively control the substantially water interface (117) during enlargement
of
the cavern walls (1A)
[000166] Referring now to Figures 9-10, 12-14, 76 and 80, the Figures depict
various
example intermediate and final cavern design shapes that can be usable with
the
present invention. An initial volume (147) can be formed for a storage cushion
during simultaneous storage and solution mining (1S), after which subsequent
cavern shapes (1B. IC, 1D) can be formed by selectively controlling the
substantially water interface (117) with placement of a salt inert cushion and
selective placement of manifold crossovers (23) and flow control devices,
until
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reaching the final cavern wall (1A of Figures 9-10, 12-14, 76 and 80) design
volume.
[000167] Construction methods (CS4-CS7) can be usable with any underground
storage
facility requiring a subterranean well for fluid communication of stored
products, for example depleted reservoirs similar to those depicted in Figures
3
and 6. The storage boundary (1A of Figures 3 and 6) represents a geologic
feature, such as a four-way dip closure reservoir or the walls of a
conventional
mine or, as described, a solution mined salt cavern, wherein subterranean
valves
can be required for stored products, posing a significant risk of escaping
through
expansion or evaporation.
[000168] Combined storage and solution mining methods (1S, 1T, CO3-007, 157)
can be
usable with any underground salt cavern storage facility. The present
invention
can be usable for combining liquid and gas storage caverns, where higher unit
value products, such as liquid hydrocarbon storage, conventionally displaced
with saturated brine rather than water and having a storage value not
necessarily
driven by short term peak loading, are not generally combined with hydrocarbon
gas salt cavern storage, wherein economics are dominated by short term peak
leveling requiring only a small portion of the design volume from caverns
generally not refilled after initial dewatering.
[000169] Liquid products of greater per unit value, generally, require lower
economic
volume turn-over or turns than, for example, a compressed product like
hydrocarbon gas, with two distinct demand cycles comprising a daily or weekly
usage of a small proportion of the stored volume to manage peak demand and a
season demand occurring over a longer time horizon, comprising cycling the
entire working storage volume between the maximum and minimum working
pressures of the cavern. Typically, the capital cost of constructing large
underground salt cavern gas storage facilities, comprising many interconnected
caverns, is less economic for seasonal demand than, for example, a depleted
reservoir, because the capital investment is higher returns on the longer
investment. As a result, salt cavern storage is conventionally used for peak
leveling of daily and weekly demand, wherein the seasonal turn-over of a lower
value per unit product cannot economically justify the construction
investment,
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or the sunk cost investment, for a significant volume of cushion gas that must
be
left within caverns to maintain the minimum working pressure supporting the
salt cavern roof.
[000170] Consequently, less capital intensive and less-efficient depleted
sandstone
reservoir gas storage is typically used for seasonal demands, while gas-tight
salt
caverns are generally used for peak leveling daily or weekly demand,
generally,
preventing the combination of contra-seasonal-demand storage combinations of
liquid and gas hydrocarbons storage facilities.
[000171] Embodiments of the methods of the present invention are usable to
reduce the
cost of constructing and operating liquid and gas storage facilities. For
example,
embodiments of the present invention can reduce costs by constructing a well
in
a single rig visit, or by providing pressurized containment for seasonal re-
filling
of a gas storage cavern with liquid hydrocarbons, water and/or brine without
further rig visits, that are conventionally required for placement and removal
of
a dewatering string through subsurface safety valve. Additional reduction of
costs include economically supplying water and disposing of brine using, for
example, the ocean to provide larger facilities with a plurality of more
efficient
gas-tight storage caverns that can be usable for economically supplying both
peak leveling and seasonal gas demands.
[000172] Conventional designs include, for example, the dual wells to a single
cavern
depicted in Figures 13 and 14. The Figures show two or more conduit strings
(2) and selectively controllable subterranean valves (74), engaged to
associated
wellheads (7) and subsea or surface valve (64) trees (10), that are usable to
selectively control injection of salt inert fluids and water to form a cushion
storage volume (147), after which a cushion storage space working pressure
(WP) is usable to selectively control a substantially water or fluid interface
(117) for underground storage operations (1S), while solution mining (1). For
example, hydrocarbon gas may be stored within the upper cushion volume (147)
during a weekend forcing saturated brine from the cavern and, then, released
from storage during weekday peak demands as water is injected into the cavern
to solution mine the lower end of the cavern and to reduce working pressure
(WP) reductions caused by product withdrawal.
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[000173] Initially, any salt inert fluid followed by any storage valued salt
inert fluid, for
example, diesel or hydrocarbon gas, can be trappable through injection and
lower specific gravity floatation between the final cemented casing shoe
(3,16)
and a substantially water interface (117), usable for selectively controlling
salt
dissolution (1). For example, nitrogen gas can be used to form the initial
storage
cushion volume; after which, hydrocarbons valued for various consumer
demands can be usable as a salt inert fluid for storage operations (15) or
compressed air, generated from wind energy and valued for release to a
pneumatic motor driving an electrical generator, can be usable as a salt inert
fluid for storage operations (1S) while solution mining (1).
[000174] Conventional theories, relating to support of the cavern roof and
working gas
pressures within a cavern, use shapes (1D), similar to those of Figures 10 and
14, to provide an arching salt deposit roof capable of lower working pressures
than, for example, shapes (1A) similar to Figures 9, 10, 12 and 13. Apparatus
and methods of the present invention can be usable with any cavern shape and
working cavern pressure. Higher and lower working pressures (WP), associated
with various cavern shapes, can be at least partially controllable with fresh
water
injection, brine generation and/or brind displacement during combined
operations (IT, CO3-007) to help maintain cavern pressure during stored
product release, wherein product storage drives the water interface (117) and
associated brine extraction and/or dewatering.
[000175] Various methods for injection of water and extraction of saturated
brine can be
usable to selectively control the substantially water interface (117). For
example, a gas storage operation (1S) pump (69A of Figure 29), engaged within
a manifold crossover (23F of Figures 6, 9, 10 and 12) between controlling
valves (74 of Figures 6, 9, 10 and 12), can be operatable with release of
compressed gas to pump water into the pressurized (WP) cavern for solution
mining (1) operations, as expanding compressed gas is released from storage.
The compressed gas can be injected into the cavern for urging saturated brine
from the cavern, with the working pressure (WP) of the dewatering operation
assisted by reverse operation of the in-line subterranean pump (69A of Figure
29) for aiding brine extraction.
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[000176] Various other solution mining (1) and storage operations (1S) can be
usable
including frequent, intermittent or seasonal extraction and emptying of stored
fluids within the cavern by filling the volume (147, 1B, 1C, 1D) with fresh
water
left to fully saturate, with dissolution of a calculated salt, wall thickness
within
the tolerance of the maximum cavern design diameter using, for example, an
ocean for water supply and brine disposal and/or a u-tube conduit arrangement
method (1T) for fluid communication between brine and storage reservoirs.
[000177] The working pressure and working volume, within underground gas
storage
wells and caverns, can be invariably linked in compressible fluid storage
operations, where a large initial volume of cushion gas must remain within
caverns for the life of a convention gas storage facility to maintain the
minimum
working pressure that is necessary to prevent salt creep from adversely
affecting
the storage space and/or stability of the salt cavern roof.
[000178] Embodiments of the methods (1T, CO3-007) can be usable to positively
affect
the working volume, comprising for example the sum of a working gas volume
and cushion gas volume necessary to maintain salt cavern stability and/or for
extending the withdrawal period associated the limiting thermodynamics of
expanding gas lowering well equipment, generally measured at the wellhead.
Increased usable working volume can be achieved by filling the cavern volume
with water or brine, from for example and ocean or brine and storage
reservoir,
while using a valve controlled manifold crossover (23F of Figures 6, 9, 10, 12
and 21-26) or a conventional well design with two conduit strings, usable to
selectively control injection of water, salt inert and/or valued storage
fluids
while extracting brine or valued storage fluids. The embodiments of the
methods (1T, CO3-007) can be usable to control at least a portion of the
pressure, volume and temperature thermodynamic results of injection and/or
extraction of stored fluids, while simultaneously emptying or filling the
cavern
with water or brine.
[000179] Referring now to Figure 10, an elevation subterranean cross-sectional
diagrammatic view of construction (CS5) and combined hydrocarbon operations
(C04) method embodiments, using a manifold string (70T) with manifold
crossovers (23F, 23S) within a bored strata passageway (17) through a salt
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deposit (5). Embodiments, shown in the Figure, include using a conventional
cement retainer or expandable cement packer (139) and a manifold crossover
(23S), adapted with a conventional cement stage collar (123) for performing a
similar function to a sliding side door, wherein the cement port can be closed
after cementation through radial passageway conduits extending from the
innermost bore to the outer conduit string (2A), engaging the manifold string
(70T) to the passageway through subterranean strata (52) with a casing shoe
(16). The casing shoe (16) can comprise the expandable cement packer (139)
that can be cemented (20) in place through an intermediate casing (15) placed
and cemented (20) within a conductor casing (14), with a wellhead (7) at its
upper end.
[000180] After engaging a valve tree (10A of Figure 12) to the upper end of
the wellhead
(7), the combined operations (IS, C04) method can comprise placing an initial
water interface cushion with trapped injection and, then, forming a storage
cushion volume (147) using the faster cavern roof leaching rate, once an
initial
cavern diameter is established by indirect circulation axially down the
intermediate concentric passageway (24), and through the lower end orifices
(59) in the inner conduit string (2). The method (C04) can continue by the
combined operations of solution mining, injecting and storing a salt inert
storage
fluid (1S), within the upper end of the space (147) or cushion, to lower the
water
interface for enlargement of the initial cavern diameter, with further
indirect
and/or direct circulation through the innermost passageway (25) to various
radial passageways (75) of manifold crossovers (23S), for enlarging the lower
cavern shape (1D). Indirect circulation of water down the concentric
passageway (24), with brine returned through the innermost passageway (25),
can be changeable, after formation of the initial volume (147), to direct
circulation of water down the innermost passageway to a selected blocked
depth, using, for example, a flow controlling device such a plug, for
diverting
flow through the manifold crossover (23S) to fall downward through the storage
cushion to the water interface, with stored products retrieved from the
cushion
through the manifold crossover (23S) by indirect circulation. Subsequent
combined operations (C04) can comprise, for example, alternating gas storage
peak demand trading and solution mining operations (1S), wherein the sloped
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cavern roof is designed for emptying the cavern of water and refilling it,
accounting for differing rates of salt dissolution between the walls and roof
until
reaching the final wall (1A) shape. Thereafter, the embodiments of the
combined operations method (C04) can include, for example, peak leveling
trading of gas for using a smaller portion of the cavern, refilling the cavern
for
season gas storage, and compensating for natural salt creep, resulting from
strata
overburden pressures, with subsequent seasonal salt dissolution.
[000181] Inclusion of a plurality of smaller diameter radial passageway
manifold
crossovers (23S of Figures 42-44), usable with a plurality of shorter
conventional flow controlling device (61 of Figures 39-41) lengths provides a
means for depth critical adjustments, that can be necessary when solution
mining operations encounter unexpected subterranean salt deposit features, or
wherein high injection rates of water are to be spread over various depths
through several manifold crossovers (23S), instead of injection through a
large
bore at a single depth.
[000182] Various larger bore manifold crossovers, for example 23Z of Figure
38, can be
included for sonar measuring devices to exit a manifold string entering the
cavern, to take the sonar measurements. Alternatively, measurements can be
taken through the manifold string conduits to adjust solution mining
operations
and to manage unexpected subterranean features encountered during solution
mining.
[000183] Referring now to Figures 11 and 12, elevation subterranean cross
sectional
diagrammatic views of construction (CS6) and combined hydrocarbon
operations (C05) method embodiments are shown, which can be usable with a
manifold string (76N) and manifold crossovers (23F, 23T). The Figures show a
chamber junction (43) final casing (3) that can be cemented (20) within a
conductor (14) casing for forming a single main bore (6) and wellhead (7) for
engagement of a valve tree (10A). The Figures show a plurality of strata bores
(17) that have been drilled through a salt deposit (5) to intersect at their
lower
end. The Figures include a plurality of conduit string (2) liners (19) with
hangers and production packers (40), which are engaged with the chamber
junction (43) exit bore conduits (39), after which the manifold crossovers
(23F,
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23T) assembly can be connected (137) with, for example, packer anchors
secured to the production packers (40) with a valve tree (10A) that can be
engaged to the upper end of the wellhead, securing the tops of the various
conduit strings (2, 2A, 3 and 14).
[000184] The combined underground storage and solution mining method (C05) can
be
usable to inject (31) fresh water into the left side well, taking returns (34)
through the right side well, wherein a plug (25A) within a manifold crossover
(23T) can direct flow from the right well into the concentric passageway (24)
to
enter the innermost passageway (25) above the flow control device (61) within
the upper manifold crossover (23F). The upper manifold crossover (23F) can
comprise, for example, a plug (25A of Figure 15) or a fluid pump (69A of
Figure 29), that can be usable to both divert and selectively control fluid
flow
through the subterranean valve (74) controlled upper manifold crossover (23F),
wherein fluid communication is further selectively controlled by valves (64)
of
the valve tree (10A).
[000185] Water and a salt inert fluid are injectable (31) and trappable under
the
production packers and casing shoe (16) or within, either or both, cavern
chimneys formed by the wells exiting the chamber junction (43), if a manifold
crossover (23S of Figure 10) is adapted with a cementing stage tool (123 of
Figure 10) and a cement packer (139 of Figure 10) is used to seal either or
both
cavern chimneys. As the substantially water interface (117) is moved axially
upward, the left side conduit can be sequentially severed (140) to adjust the
level at which water is placed within the intermediate cavern walls and
provide
unrestricted sonar measurements.
[000186] One or both wells exiting the chamber junction (43) can be usable to
leach a salt
inert storage cushion fluid volume (147 of Figures 10, 13, 14, 76 and 80) and
can be further usable to store fluid during combined operations (C05). The
liquid interface (117) can be selectively movable with working pressure, and
the
interface (117) can be raised upward as the cavern volume (1B, 1C, 1D) is
formed through salt dissolution. Water insoluble strata can fall and
accumulate
(1G) at the cavern lower end with extraction (34) through orifices (59) in the
right side well conduit (2), during the process of extracting fine particles
and
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small solids, and leaving the larger particles (133) to form by permeability
(132
of Figure 2), within the insolubles accumulated (1G) at the cavern floor.
[000187] Referring now to Figures 3, 5-6, 9-14, 76 and 80-83 depicting various
preferred
method embodiments (1S, CS1-CS7, C01-007, 1T, 157), wherein various
methods and apparatus described herein can be usable and combinable with
various other methods and apparatus of the present invention to form other
embodiments, that can be usable to selectively control pressures during
construction and/or hydrocarbon operations, storage or solution mining for one
or more substantially hydrocarbon and/or substantially water wells from a
single
main bore (6).
[000188] As demonstrated by various described construction (CS1-CS3) and
combined
operations (C01-0O2) methods, the present invention can be usable to
accomplish various operations performable through a completion to one or more
wells through a single main bore (6), and is further adaptable to perform, for
example, any pressure controlled circulation of fluids through a completion
string for acid cleanups, matrix acid frac stimulations or proppant frac
stimulations, gravel packs, jet pump operations, gas lift operations, other
fluid
operations through a completion string normally requiring circulation, with
for
example, coiled tubing.
[000189] Referring now to Figures 15 and 16, views of a conventional wireline
plug
(25A) and wireline rig (4A), respectively, are depicted. The Figures show a
flow control device (61) placeable through engagement with a cable (11) of a
wireline or slickline (4A) rig (4), with a hoisting (12) apparatus for
conveyance
through a lubricator (8) and blow out preventer (9) engaged to the top of a
valve
tree (10), that is secured to a wellhead (7) in communication with the
innermost
passageway of a manifold string, for placement within the passageway through
subterranean strata to selectively control pressurized fluid flow. Various
example flow control apparatuses (61) are depicted and comprise a: plug (25A)
with a cable engagable connector (68) and mandrels (89), a straddle (22 of
Figures 39-44), an orifice piston (128 of Figures 27-28), a pump (69A of
Figure
29) and bore selectors (47 of Figure 37, 51-53 and 47A of Figures 35-36), that
can be placeable, usable and retrievable from the innermost passageway (25) of
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the present invention to selectively control pressurized fluid flow, wherein
other
conventional devices and flow controlling devices of the present inventor are
also usable.
[000190] Referring now to Figures 17, 21, 32, 38, 42 and 71, the Figures
depict plan
views with dashed lines representing additional conduits (2B, 2C, 2D), usable
to
form additional concentric passageways (24A, 24B, 24C) that can be engagable
with other manifold crossovers, for example, 23C of Figures 17 to 20, 23F of
Figures 21 to 26, 231 of Figures 31 to 34, 23Z of Figure 38, 23S of Figures 42-
44 and 23V of Figures 71 to 73, to form various other manifold crossover
embodiments (23) and/or manifold strings. In a manner similar to the manifold
string (70W) of Figure 31, any number of additional concentric conduits and/or
conduit strings engagable with various manifold crossovers can be configurable
in various arrangements to selectively control pressurized fluid mixture flow
through a plurality of concentric passageways, using a valve disposed across
the
innermost passageway, whereby access through the innermost passageway
remains usable for conveying flow controlling devices (61).
[000191] With regard to Figures 17 to 20, various views of a manifold
crossover (23C)
embodiment are shown, depicting concentric conduits (2, 2A) on upper and
lower ends of an expanded diameter outer concentric conduit (2A), with walls
angularly arranged for relatively high flow stream velocities and with an
enlarged internal diameter to form equivalent or larger cross-sectional flow
areas to, for example, reduce the risk of erosion or flow cutting of the
manifold
crossovers (23C) walls, usable to form embodiments of valve controlled
crossovers (for example 23F of Figures 21 to 26).
[000192] Referring now to Figure 17, a plan view with line A-A associated with
Figure
18, of a manifold crossover (23) embodiment (23C), depicting fluidly separated
intermediate concentric passageways (24X and 24Y) formed within the
intermediate concentric passageway (24), about the innermost passageway (25).
[000193] Figure 18 depicts an elevation cross-sectional view along line A-A of
Figure 17,
illustrating a manifold crossover (23C). The Figure shows the left side
fluidly
separated passageway (24Y) ending at a lower end wall for diverting fluid
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communication through lower radial passageways (75), with the right fluidly
separated passageway (24X) ending at an upper end wall for diverting fluid
communication through the upper radial passageways (75). The engagement of
a flow control device, for example a plug (25A of Figure 15), within the
receptacle (45) between upper and lower radial passageway (75) orifices (59)
can effectively divert fluid communication from the concentric passageway (24)
to the innermost passageway (25), and vice-versa.
[000194] Referring now to Figure 19, the Figure depicts a projected view of
Figure 18
along section line A-A of Figure 17, with detail line B associated with Figure
20
of a manifold crossover (23C). The Figure shows the ends (90) of the manifold
crossover engagable between conduits of conduit strings (2, 2A) of a manifold
string, wherein the innermost passageway can be usable to convey flow control
devices through the string. The intermediate concentric passageway (24) is
shown fluidly separated into flow stream passageways (24X and 24Y) to cross
over fluid communication from the innermost passageway (25) to the concentric
passageway (24), and vice-versa, when a flow control device is engaged with
the receptacle (45) between radial passageway (75) orifices (59) The manifold
crossover (23C) can be usable with a valve controlled manifold crossover (23F
of Figures 21-26), wherein a valve control line passageway (141) can be
placeable within walls between fluidly separated passageways (24X, 24Y) for
subsequent continuance within the concentric passageway (24) or for external
engagement with the string, as shown in Figure 17.
[000195] Figure 20 depicts a magnified view of the portion of the manifold
crossover
(23C) within detail line B of Figure 19, with dashed lines showing hidden
surfaces, and further illustrates the arrangement of passageways (24, 25, 24X,
24Y and 141) about and around the radial passageway orifices (59), connecting
the passageways (24, 25 of Figure 18) formed by the inner (2) and outer
conduits (2A).
[000196] Figures 21 to 26 depict various views of a valve controlled manifold
crossover
(23F) embodiment. The Figures include conventional valves (74) that can be
suitable for subterranean use. The valves are shown, for example purposes, as
fail-safe flapper (127) type subsurface safety valves, with control lines
(79), that
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can be engaged to the upper and lower ends (90 of Figures 17-20) of a manifold
crossover (23C of Figures 17-20) to form a valve controlled manifold crossover
(23F), with upper and lower ends engagable between conduits (2, 2A) of a
larger
manifold string.
[000197] Referring now to Figures 21, 22 and 23, the Figures depict plan,
elevation cross-
sectional and isometric projection views, respectively, with break lines
showing
removed sections of the Figure 22 cross-section, along line C-C of Figure 21,
and projected to form the isometric view of Figure 23, with detail lines D, E
and
F associated with Figures 24, 25 and 26, respectively, of a valve controlled
manifold crossover (23F). The Figures illustrate flapper (127) type valves
(74)
through which flow control devices may be conveyed, and through which a plug
(25A) flow controlling device can be installed within the receptacle (45) to
divert fluid communication between the upper innermost passageway (25),
through the upper radial passageway (75) and the fluid separated
concentrically
disposed passageway (24X), to the lower intermediate passageway (24). At the
same time or simultaneously, fluid communication can be diverted through the
upper concentric passageway (24), through the fluidly separated concentric
passageway (24Y) and lower radial passageway (75), to the lower innermost
passageway (25). Fluid flow to both fluidly communicated flow streams can be
selectively controllable by the upper and lower valves (74) and control lines
(79).
[000198] Figure 24 depicts a magnified view of the portion of manifold
crossover (23F)
within detail line D of Figure 22. The Figure illustrates the upper
conventional
flapper (127) valve (74) with a flow tube (142) that can be engagable with the
flapper (127) urged by a piston (143) pressured through the control line (79)
axially downward to hold the valve open. A loss of hydraulic pressure in the
control line (79) can release the piston (143) force, and a spring (144) can
be
used to shut the valve with pressure beneath the flapper assisting closure.
The
valve can be engaged to the inner concentric conduit string (2) and contained
within the outer concentric conduit string (2A), with the lower valve control
line
passing through the concentric passageway (24) or, alternatively, on the
exterior
of the assembly as shown.
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[000199] In a manner similar to the manifold crossover (23C), the diameter of
a conduit
string (2, 2A) can be adjustable within any confining spaces to accommodate a
loss of cross-sectional area. For example, the diameter of the conduit 2A of
Figures 21-26 is increasable to provide improved flow properties past the
valve
(74) bodies extending into, and partially blocking, the depicted concentric
passageway (24).
[000200] Referring now to Figure 25, a magnified view of the portion of
manifold
crossovers (23C and 23F) within detail line F of Figure 23 is shown. The
Figure
depicts the cable engagable connector (68) of the plug (25A), that is deployed
through, and engaged within, the upper innermost passageway (25) to divert
fluid communication from the innermost passageway to the upper radial
passageway (75) orifices (59).
[000201] The Figure shows control and/or measurement lines (79) that can be
usable to,
for example, operate the lower valve (74) and to operate measurement devices
for the substantially water interface in a solution mining and/or underground
storage cushion operation, with hydraulic or electrical signal passage through
the wall between the fluidly separated passageways (24X, 24Y) and the
intermediate concentric passageway (24) or, alternatively, by engagement to
the
outside diameter of the outer string (2A). The control or measurement cable or
line (79) can pass through the concentric passageway, between concentric
conduits (2 and 2A), or enter the surrounding passageway about the manifold
crossover (23).
[000202] Similar arrangements can be usable for passing control and/or
measuring
conduit or cable lines (79) from the surrounding passageway (55 of Figures 3,
6
and 9-12) into a concentric passageway (24 of Figures 3, 6 and 9-12) to
bypass,
for example, a packer (40 of Figures 3, 6, and 9-12). Thereafter, the cables
can
re-enter the surrounding passageway and be strapped to the assembly as it is
placed within the passageway through subterranean strata (52 of Figures 3, 6,
and 9-12).
[000203] Figure 26 depicts a magnified view of the portion of manifold
crossovers (23C
and 23F) within detail line E of Figure 22. The Figure illustrates the plug
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diverting fluid communication from the lower innermost passageway (25) to the
radial passageway (75) orifices (59), with control lines (79) exiting the
bottom
of the wall between fluidly separated passageways (24X, 24Y), both internal
and
external to the outer conduit (2A).
[000204] Referring now to Figures 27 and 28, the Figures depict a plan view
with line G-
G and elevation cross-section along line G-G, respectively, of an orifice
piston
embodiment (128). The Figures show a housing (114) with outer diameter seals
(66), upper and lower orifices (59) at the ends of the associated passageway
that
can be usable for passage of a conduit or cable (11 of Figure 15). The orifice
(59) passageway may be sealing or provide partial fluid communication to aid
placement, removal and use within a method. Methods of use include, for
example, placement within manifold crossover (23C, 23F, 231, 23T, 23Z)
receptacles between innermost passageway orifices, wherein the connectors,
shown for example as mandrels (89), are engagable with receptacles to divert
all
or part of fluid communication from the innermost passageway from crossing
radial passageways fluid flow streams above and below the orifice piston
between intermediate and innermost passageways, similar to a choke or plug
(25A of Figures 21-23 and 25-26), when cable or conduits are passed through
the flow control device (61) orifice piston (128) and innermost passageway.
Differential pressures against the upper and lower piston surfaces can be
usable
to place and/or hold the orifice piston (128) in place or to aid in its
removal
during, for example, the under-balanced cable perforating operations of
Figures
3 and 6; the under-balanced coiled tubing drilling operations of Figure 3; or
the
coiled tubing cleanout of insolubles blocking a manifold string in the
solution
mining and combined operation methods of Figures 9-14.
[000205] Figure 29 depicts an isometric view of a fluid motor and fluid pump
(69A) flow
control device (61) with a cable connection (68) for placement and removal
through the innermost passageway. The pump can be usable within receptacles
in various manifold crossovers (for example 23C, 23F, 231, 23T, 23Z), with
upper and lower fluid turbines (112) placeable between crossing fluid
communicating passageways. The energy from one fluid mixture flow stream
can be partially transferred to the other through a shaft (113) connecting the
two
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turbine or impellor (112) arrangements, for example, gas expansion from an
underground storage cavern driving one impellor also drives the other
impellor,
which can be usable to pump water into the storage cavern for solution mining
operations and, conversely, with fluid pumped into the cavern during solution
mining assists either storage fluid or brine extraction from the cavern. For
example, the temperature of gas expansion can be reduced by decreasing the
decompression of stored gas, thereby increasing the withdrawal periods
achievable during seasonal drawn down of a cavern, before shutting in on
minimum equipment operating temperatures. If differing rotational speeds
between impellors are required, for example, when expanding gas through one
turbine is driving the other liquid pumping impellor with a higher torque
requirement, gearing arrangements, such as planetary gearing are usable within
the housing (114).
[000206] Referring now to Figures 30 and 31, the Figures show diagrammatic
views of
the manifold crossover (23F) of Figures 21-26 forming a manifold string (70U)
embodiment of Figure 30, and the manifold crossover (23F of Figures 21-26)
combinable with manifold crossovers (231 of Figures 32-34; 23T of Figures 6,
11-12 and 54-58; 23Z of Figure 38; 23S of Figures 10 and 42-44; and 23V of
Figures 71-73) and configurable in various arrangements to replicate the valve
controlled manifold string (70W) embodiment of Figure 31. The Figures
include various usable flow paths and fluid mixture flow stream variations
with
a plurality of valve (74) configurations, wherein further embodiments are
possible with addition conduits, passageways and valves.
[000207] The Figure 30 manifold string (70U) depicts a flow stream Fl flowing
axially
upward within the lower end concentric passageway (24) and crossing over
above the flow control device (61), below the upper valve (74A), to the upper
end innermost passageway (25). In addition, the Figure shows a flow stream F2
flowing axially downward within the upper end concentric passageway (24) and
crossing over below the flow control device (61), above the lower valve (74B),
to continue through the lower end innermost passageway (25).
[000208] The Figure 31 manifold string (70W) depicts a flow stream Fl flowing
axially
downward within the upper end innermost passageway and crossing over above
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the upper flow control device (61), below the upper valve (74A), to the lower
end concentric passageway (24). In addition, the Figure shows a flow stream F2
flowing axially upward within the lower end additional concentric passageway
(24A) and crossing over above the lower flow control device (61), above the
lower valve (74C), to the innermost passageway (25) and crossing over again,
below the upper flow control device (61) to the upper end concentric
passageway (24). Further, the Figure includes a flow stream F3 flowing axially
upward through the lower end innermost passageway (25) and crossing over
below the lower flow control device (61), to continue through the upper end
additional concentric passageway (24A). All flow streams (F1, F2, F3) can be
controlled by selectively controllable valves (74A, 74B, 74C) of the innermost
passageway (25).
[000209] Referring now to Figures 32, 33 and 34, the Figures show plan,
elevation cross
sectional and isometric projection views, respectively, with dashed lines
showing hidden surfaces and break lines showing removed sections of Figure 33
cross-section, along line H-H of Figure 32, projected to form the isometric
view
of Figure 34, of a manifold crossover (231) embodiment, with additional
intermediate concentric passageways (24A, 24B of Figure 32). The Figures
illustrate an inner conduit (2), intermediate conduit (2A), and outer conduit
(2B)
forming an innermost passageway (25), intermediate concentric passageway
(24), and additional intermediate concentric passageways that can be usable
for
fluid communication.
[000210] Dependent upon the number of intermediate passageways between the
innermost passageway (25) and the concentric passageway (24A), that can be
fluidly connected by the radial passageway (75), one (24X) or more (24Y)
fluidly separated passageways can pass through the manifold crossover (23I)
without being diverted to fluidly communication between one (24) or more
upper and lower intermediate passageways. The third fluidly separated
passageway (24Z) can fluidly communicate from a concentric passageway
(24A), through radial passageway (75) orifices (59), with the innermost
passageway (25) on opposite sides of a receptacle (45) for engagement of a
flow
control device. Engagement of a flow controlling device within the receptacle
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(45), between radial passageway orifices (59), can be usable to divert or
crossover all or a part of fluid mixture flow streams being communicated
through the innermost passageway (25) and the fluidly engaged (59, 75)
concentric passageway (24A).
[000211] Figures 35 and 36 depict plan views with line I-I and elevation cross-
section
along line I-I, respectively, with break lines showing removed portions, of an
embodiment of a flow controlling device (61) bore selector (47A). The depicted
embodiment can be usable to selectively divert fluid flow and/or further flow
controlling devices through a plurality of orifices. The Figures show an upper
straddle (22) wall branching to a plurality of orifices (59), with guiding
surfaces
(87), that can be usable with a chamber junction (43 of Figure 38) additional
orifices to communicate devices and/or fluids. The bore selector (47) can be
engagable at a receptacle (45B) for placement, with mandrels (60) engagable to
an associated receptacle (45 of Figure 38). The upper and lower straddle (22)
walls can be usable to control flow of a surrounding conduit orifices (23, 59
of
Figure 38), with passage of fluids through, for example, an internal one-way
valve (84) or other internal flow controlling device (61) to aid placement,
removal and/or usage of the bore selector.
[000212] Referring now to Figure 37, a plan view with line J-J above an
elevation cross-
section along line J-J, with a break line showing a portion removed, of a bore
selector (47) and flow controlling device (61) is shown. The Figure shows a
guiding surface (87) for fluids or devices through the bore selector orifice
(59),
that can be alignable with an associated chamber junction (for example 43 of
Figure 38), wherein the guiding surface (87) wall can block access to an
additional orifice and exit bore axially aligned with the innermost
passageway,
and/or other radially disposed additional orifices. An extension of the bore
selector (47) outer wall can also form a straddle (22) that can be usable to
block
adjacent manifold crossover orifices (23, 59 of Figure 38).
[000213] Referring now to Figures 32-34, 38 and 42-44, the Figures depict
manifold
crossovers (23) that can be usable for diverting flow between the innermost
passageway (25), through an intermediate concentric passageway (24), to a
passageway disposed radially outward, such as an additional concentric
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passageway (24A) or a passageway surrounding the outer conduit (2A). The
radial passageway (75) comprises fluidly separated passageways (24X, 24Y) or
the bore of a conduit (39).
[000214] Figure 38 depicts a plan view with line K-K above an elevation cross-
section
along line K-K of a manifold crossover (23Z) embodiment, within a manifold
string (70G), with break lines showing removed portions. The Figure
illustrates
a chamber junction (43) with three radially disposed exit bore conduits (39)
truncated (46) at an enclosing concentric conduit (2A), forming radial
passageways (75) engaged through radial passageway orifices (59) to the
chamber (41) for forming an innermost bore (25) with a fourth exit bore
conduit
(39) axially aligned with the upper internal passageway (25), that is shown
engaged to the lower end internal conduit (2) and concentrically disposed
within
the concentric conduit (2A). The Figure shows the manifold crossover (23Z)
with a flow diverter (21), and the ends (90) of the manifold crossover (23Z)
can
be engagable between conduits of a manifold string (70G).
[000215] The example manifold string (70) has a plurality of adjacent
passageway orifice
(59) crossovers (23), axially below the chamber junction (43), with associated
receptacles (45) for engaging flow controlling devices, such as bore selectors
(47A of Figures 35-36 or 47 of Figure 37) or straddles (22 of Figures 39-41).
The devices can divert fluid from the innermost passageway (25) to the
concentric passageway (24) through the adjacent passageway orifice (59)
crossovers (23) by blocking a portion of the innermost passageway (25), or the
devices can prevent communication between the passageways by straddling the
orifices (59).
[000216] Example fluid mixture flow stream arrangements include injecting (31)
fluid
through the upper end innermost bore (25) and diverting it, with a bore
selector
(47A of Figures 36-36), through the three radial passageways (75) to the
passageway surrounding outer conduit (2A). The fluid flow (34) through the
lower innermost passageway (25) can cross over (23) at the adjacent
passageway orifices (59), below the bore selector and continue axially upward
(34) in the concentric passageway (24).
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[000217] Referring now to Figures 39, 40 and 41, the Figures depict plan,
cross- sectional
and magnified detail views, respectively, with the portion within detail line
M of
Figure 40 cross-section, along line L-L of Figure 39, magnified in Figure 41
for
illustrating an adapted prior art flow control device (61), that can be usable
as a
bore selector (47A). The Figure shows a straddle (22) with a flow control
device connection (96) that is depicted, for example, as snap-in mandrel (60)
with a spring (144) locking arrangement to prevent dislodgement during fluid
communication. A placement receptacle (45B) can be usable for engaging and
conveying the apparatus through the innermost passageway for engagement with
an associated receptacle.
[000218] The straddle (22) portion internal bore (25) can be usable as a
radial passageway
when blocking orifices of a manifold crossover (for example 23S of Figure 42-
44), or the internal bore may open, or be partially or fully blocked, to
selectively
divert fluid to orifices (59) within the straddle (22) wall, usable as fixed
chokes
and/or protection against flow cutting sealing surfaces within which the
straddle
or bore selector is engaged. Seals (66), for example, chevron type seals (97),
can be usable for blocking flow past the straddle (22) wall or for diversion
through the protective and/or fixed choke orifices (59). Any orientation means
suitable for subterranean use, for example keys and slots or helical surfaces,
can
be usable to align the bore selector (47A) fixed choke and/or protective
orifices
(59) with radial passageways of the exit bore conduits (39).
[000219] Figures 42, 43 and 44 depict plan, elevation cross-sectional and
isometric
projection views, respectively, with Figure 43 cross-section, along line N-N
of
Figure 42, projected to form the isometric view of Figure 44 of manifold
crossover (23S) embodiment. The Figures illustrate an additional concentric
conduit (2B), shown as a dashed line, that can be usable to form an additional
concentric passageway (24A of Figure 42) about a concentric conduit (2), that
is
shown engaged with an adapted chamber junction (43) for forming a concentric
passageway (24) through which exit bore conduits (39), with internal radial
passageways (75), can fluidly communicate between the innermost passageway
(25) and the additional passageway (24A of Figure 42) or surrounding
passageway, formed when the assembly is placed within the passageway
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through subterranean strata. The assembly can be engagable between conduits
of manifold strings at upper and lower ends (90). An axially aligned exit bore
conduit (39 of innermost bore (25) diameter can be disposed immediately below
the radially extending exit bore conduits (39), wherein a bore selector (47A
of
Figures 39-41) can be engagable with the receptacle (45) to selectively
control
fluid flow through the radial passageways (75) and placeable, through the
axially aligned exit bore conduit, for engagement with other manifold
crossovers.
[000220] Flow control devices (61) can be usable as a bore selector (47A). For
example,
the straddle (22) of Figures 39 to 41, can be placeable and engagable with an
internal receptacle (45B) for engagement to the manifold crossover receptacle
(45). The flow control device can be usable to form an axially aligned radial
passageway (75A) that can be fluidly separated from radial-extending
passageways (75) with various seals (66), including for example, interlocking
type seals (97), which can be usable for pressure containment about orifices
(59)
for protection from flow cutting and/or fluid mixture abrasion. Figures 43 and
44 show a flow control device engagement (96), that can be usable for
orienting
the bore selector orifice (59) to bore passageways.
[000221] Comparisons of Figures 3, 6, 9-14, 16-38, 42-44, which depict various
manifold
crossovers (23), having a plurality of upper end and lower end concentric
conduits (2, 2A, 2B, 2C, 2D, 39, 148, 149), to Figures 45 to 73, which depict
manifold crossovers (23) having an upper end plurality of concentric conduits
and lower end plurality of concentric and/or non-concentric conduits (2, 39,
148,
149, 150), show a number of embodiments with various arrangements of axially
parallel and/or concentric conduits, within a single main bore, that can be
usable
with manifold crossovers of the present invention. The conduits within a
single
strata bore from, for example, a conventional dual bore wellhead and valve
tree
or traditional concentric conduit wellhead and valve tree, can be engagable
with
concentric and/or non-concentric conduits to form a single main bore that can
be
further engagable to a manifold crossover and/or chamber junction with a
plurality of lower end conduits for forming a manifold string.
[000222] Referring now to Figures 45 and 46, the Figures show isometric and
magnified
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isometric views, respectively, with dashed lines showing hidden surfaces with
and within detail line P, depicting an embodiment of a chamber junction (43).
The depicted chamber junction (43) comprises a chamber (41) and engaged (44)
exit bore conduits (39), with innermost passageways (25) extending downward
from a chamber bottom (42), that can be usable for construction methods (for
example CS2 of Figure 5). The engagement of a bore selector (for example 47
of Figure 47) is usable for boring and/or fluid communication. The upper end
(90) of the chamber junction can be engagable to a conduit of the plurality of
concentric conduits of a manifold string, with lower ends engagable to a
plurality of conduit strings.
[000223] Figure 47 depicts an isometric view of bore selector (47) flow
control device
(61) that can be usable with the chamber junction of Figures 45-46 and 48-50,
with dashed lines showing hidden surfaces. The Figure illustrates a guiding
surface (87) for devices and/or fluids, that is in communication with an
orifice
(88) engagable with the bore of an exit bore conduit through placement with,
for
example, a receptacle engagement (45B) that can be alignable with the slot
receptacle (65) and associated key, which can be fixed to the chamber of a
chamber junction, wherein the lower end engages the chamber junction bottom.
[000224] Referring now to Figures 48, 49 and 50, the Figures depict an
isometric view
with detail lines Q and R, a magnified view within line Q of Figure 48 and
magnified view within line R of Figure 48, respectively, with dashed lines
showing hidden surfaces of an embodiment .of a chamber junction (43). The
depicted chamber junction (43) includes an upper end (90) that can be
engagable
to conduits of a single main bore and placeable within or usable for boring a
strata passageway, and a lower end casing drill bit or reamer shoe (125).
After
placement, the exit bore conduits (39) can be usable as primary barriers (149)
for engagement of, for example, liner hangers or packers with a secondary
barrier (148) extending downward from the chamber (41). Fluid communicating
conduits (150, as shown in Fig. 67) orifices (59) can be usable for alignment
of
bore selectors or engagement of subsequent chamber junctions, and fluid
communication through lower end orifices (59) associated with the drill bit or
reamer shoe (125) during boring or placement. After placement, a bore selector
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guiding surface can be usable to place drilling assemblies, through the exit
bore
conduits (39), to whip-stocks (124) at the lower end, which can be further
usable
to laterally and fluidly separate the separated well bores under a single main
bore.
[000225] Figures 51, 52 and 53 depict an isometric view, an upwards side
elevation view,
and a front elevation view, respectively, with dashed lines showing hidden
surfaces of a flow controlling device (61) bore selector (47).The depicted
flow
controlling device (61) bore selector (47) can be usable with chambers
junctions, similar to Figures 54-58, with a guiding surface (87) for devices
and/or fluids, wherein a flow control device engagement (96), shown as a
helical
alignable mandrel, can be usable to orient the bore selector orifice (59) to
an exit
bore passageway. The Figure includes an innermost bore aligned receptacle
(45B) in the guiding surface that can be usable for placement and retrieval of
the
bore selector.
[000226] Referring now to Figures 54 to 58, the Figures depict a manifold
crossover
embodiment (23T) usable as manifold string (76H) that can be usable to
minimize frictional resistance to flow in high velocity or high erosion
environments.
[000227] Referring now to Figure 54, the Figure depicts an isometric view of
an adapted
chamber junction manifold crossover (23T), associated with Figures 55 to 58.
Figure 54 illustrates an inner concentric string (2), outer concentric string
(2A)
or second main bore conduit with ends (90) engagable to conduit strings of a
single main bore. The chamber junction (43) can be adapted to form a manifold
(43A) with the addition of receptacles and a radial passageway (75) blister,
located between the exit bore conduits (39) and the chamber junction bottom
(42) about which the upper outer concentric string (2A) extends and fluidly
engages with the blister.
[000228] Figures 55 and 57 depict plan views above elevation cross-sectional
views with
and along lines S-S and T-T, respectively, with break lines removing portions
of
the assembly associated with the cross-sections in Figures 56 and 58 isometric
views, showing the manifold crossover (23T) of Figure 54. The Figures
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illustrate the placement of a flow controlling member, shown for example, as a
cable (11 of Figure 16) placeable and retrievable blocking plug (25A), that
can
be conveyable through the inner concentric string (2) innermost passageway
(25) with a bore selector (47 of Figures 51-53) guiding surface that can be
usable to complete the chamber junction innermost passageway guiding surface
(87), excluding other exit bores. The diverting flow controlling member can be
engaged with the nipple profile receptacle (45) to block fluid communication
through the exit bore conduit (39) innermost passageway (25).
[000229] The concentric passageway (24) flow stream fluidly communicates (F1)
through
the radial passageway (75) blister to the lower end of one exit bore conduit
(39)
passageway, with the opposite exit bore conduit (39) fluidly communicating
(F2) with the chamber (41) and chamber (41) innermost passageway (25).
[000230] Commingled flow, within the chamber (41) junction manifold (43A),
from both
exit bores (39) can be operable by placing a straddle (22 of Figures 39-40
without choke orifices) across the orifice (59) of the radial passageway (75).
[000231] Referring now to Figures 56 and 58, the Figures depict projected
isometric
views with cross-sections associated with Figures 55 and 57 and break lines of
the manifold crossover (23T) of Figure 54. The Figures show isometric views
from different orientation perspectives of the radial passageway (75) blister
about the flow controlling device (61), shown as a blocking plug (25A).
[000232] Other flow controlling members, such a pressure activated one-way
valve, can
be usable to feed a substantially lighter specific gravity fluid stream, from
the
concentric passageway (24), into a heavier specific gravity flow stream, from
an
exit bore conduit, to reduce hydrostatic pressure on the second well and,
thus,
increasing flowing velocity and/or creating an under-balance.
[000233] For solution mining operations, the manifold crossover (23T) can be
usable to
fluidly separate water injection and brine extraction streams, maintaining
access
to the innermost passageway for the running of other devices, such as
severance
devices or measurement devices for measuring the shape of a salt cavern or
performing a mechanical integrity test of the final cemented casing shoe.
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[000234] The manifold crossover (23T) of Figures 54 to 58 can be adaptable
with further
conduits comprising, for example, an adjacent passageway orifice crossover (23
of Figure 38) across the radial passageway (75) orifice (59) of the exit bore
conduit (39), or to the concentric and supporting conduits of Figures 71-73,
to
form a manifold crossover (23V of Figures 71-73). Access to innermost
passageways of supporting flow conduits (150, as shown in Fig. 67), located
below the chamber (41), is not required. Alternatively, the additional exit
bore
conduits (39) can be increasable from two to four, by adapting the additional
chamber junction with additional orifices aligned with supporting flow
conduits
(150, as shown in Fig. 67), to provide access to their innermost passageway.
[000235] Referring now to Figures 59 to 71, the Figures depicting various
configurations
and/or apparatuses for a construction method (CS8) embodiment. Embodiments
of the method (CS8) can be usable with a plurality of exit bore (39)
arrangements that can be selectively accessible through a chamber junction
(43)
with one or more bore selectors (47) engagable with an associated plurality of
additional orifices. Additional conduits (150), supporting fluid communication
to or from the single main bore, can be placeable about exit bore conduits of
a
chamber junction arrangement to, for example, fluidly communicate with
concentric passageways, not requiring innermost bore access, or to align bore
selectors or engage conduit arrangements with large cross-sectional areas and
associated forces, in the event of a breach of a primary barrier (149),
wherein a
usable secondary barrier (148) is available.
[000236] Prior art expandable metal junctions, as described in Figure 4, and
conventional
multilateral technologies are, generally, unable to provide well branches with
both primary (2, 39, 149) and secondary (2A, 148) conduit barriers, with
associated usable concentric or annular passageways for monitoring pressure
between these barriers, through fluid communication. Concentric passageways,
between conduit pressure barriers, can be usable for various associated well
operations, for example, fluidly circulating a higher specific gravity kill
fluid to
replace a failed primary barrier conduit barrier (2, 39, 149).
[000237] Manifold strings (70, 76) and/or manifold crossovers (23) can be
usable with the
construction method (C8) to provide selective control of pressurized fluid
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communication within and about these barriers, for one or more wells below a
single main bore, through a single wellhead and valve tree to, for example,
provide a single subsea tree, which can be usable with gas lift and/or water
injection for production from multiple wells. Alternatively, uses can include
the
selective control of a plurality of wells to one or more underground storage
caverns, during solution mining and/or underground storage operations.
[000238] Figure 59 depicts an isometric view of an arrangement (146) of a bore
selector
(47), an upper chamber junction assembly (145A), and lower chamber junction
assembly (145B), illustrating a construction method (CS8). The conduit above
the upper connection (137) is removed to show the bore selector (47) of
Figures
63-64, that can be placeable through a single main bore and engagable to the
upper chamber junction (43) of Figures 61 and Figures 66-67, engaged with a
connector (137) to the lower chamber junction (43) shown in the plan view of
Figure 60, wherein the entire assembly (146) is shown in the plan view of
Figure
62.
[000239] Referring now to Figures 60, 61 and 62, the Figures show plan views
of the
lower chamber junction assembly (145B), upper chamber junction assembly
(145A) and fully assembled arrangement (146) of Figure 59, respectively. The
Figures show a preferred construction method (CS 8) with the Figure 60 chamber
junction (43) of similar construction to the chamber junctions of Figures 45-
46
and 48, and with no overlap of exit bore internal diameters for providing
fluidly
separated exit bores guiding surfaces (87) and innermost passageways (25) with
fluid communicating conduits (150, as shown in Fig. 67). The fluid
communicating conduits can be usable for fluid communication with, for
example, fluidly separated passageways (24X, 24Y and 24Z) from a
circumferentially segmented concentric passageway, or usable as receptacles
(45A) for a bore selector, similar to that of Figure 47. In addition, the
fluid
communicating conduits can be usable to engage and/or to fluidly communicate
with the upper chamber junction (43), as shown in Figure 61. The exit bores'
inside diameters overlap in a cloverleaf shape which can be usable with the
bore
selector, of Figures 63-64, to select the right most exit bore passageway, as
shown Figure 62 plan view. The guiding surfaces (87) of the bore selector
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extension (48) can be engaged within the cloverleaf shape to complete the
right
most bore circumference.
[000240] Figures 63, 64 and 65 depict plan, elevation cross-sectional and
isometric
projection views of the cross-section, respectively, of the bore selector (47)
flow
controlling device (61) of Figures 59 and 62, with break lines showing removed
portions in the Figure 64 cross-section, along line V-V of Figure 63,
projected to
form the isometric view of Figure 65. The Figures illustrate the guiding
surface
(87) extending to an extension (48), which can be usable to complete, for
example, the circumference of exit bores of the chamber junction of Figure 61
for conveyance of devices and/or for fluid communication to a selected bore,
while excluding other bores. The bore selector (47) can be rotatable to
various
bores and engagable with connectors (96) to the receptacles (45A of Figure
61).
[000241] Referring now to Figures 61, 66 and 67, the Figures depict plan,
elevation cross-
sectional and isometric projection views, respectively, of a chamber junction
(43) and construction method (CS8), with break lines showing removed portions
in Figure 66 cross-section, along line U-U of Figure 61, projected to form the
isometric view of Figure 67, of the upper chamber junction assembly (43) of
Figures 59 and 62. The Figures illustrate an upper end connector (137) that
can
be engagable with a single main bore conduit and a lower end connector (137)
that can be engagable with, for example, the upper end of the lower chamber
junction of Figures 59-60 or another assembly within the single main bore. The
chamber (41) and exit bores (39) can form primary barrier conduits (149) with
lower end seal stacks (66), engaged with the upper end bores of Figure 60,
within a secondary conduit barrier (148). Fluid from, for example, lower end
annular spaces associated with the well bore extending from the chamber
junction (43 of Figure 60), can be communicable through supporting fluid
communication conduits (150) for measurement (13 of Figure 1) at the single
main bore upper end wellhead.
[000242] Figures 68, 69 and 70 depict plan views of various example
combinations of
conventional sized conduit configurations, including four 13 3/8 inch
diameter,
three 13 3/8 inch diameter, and two 13 3/8 inch diameter primary barrier
configurations, respectively, of construction method (CS8) that can be usable
to
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adapt chamber junctions of Figures 45-46, 48-50, 54-58, 59-62 and 66-67.
Figure 68 illustrates four 13 3/8 inch outside diameter primary barrier
conduits
(149) within a 36 inch outside diameter secondary barrier conduit (148), with
five 5 inch outside diameter supporting pressurized fluid communication
conduits (150). Figure 69 depicts three 13 3/8 inch outside diameter primary
barrier conduits (149) within a 32 inch outside diameter secondary barrier
conduit (148), with three 6 inch outside diameter supporting fluid
communication conduits (150). Figure 70 shows two 13 3/8 inch outside
diameter primary barrier conduits (149) within a 30 inch outside diameter
secondary barrier conduit (148), with four 5 inch outside diameter and two 8
5/8
inch outside diameter supporting pressurized fluid communication conduits
(150). The exemplary outside and inside diameters illustrated are
reconfigurable
to provide various pressurized fluid communication ratings, with annular
spaces
between outside diameters of the conduits (149, 150) and within the secondary
barrier conduit (148) inside diameter, also usable for fluid communication.
[000243] Conventional well construction and operation practices, generally,
dictate the
use of conventional sized conduits to facilitate the use of conventional
tooling
and apparatus. This use includes conventional flow controlling devices that
can
be placeable through the innermost passageway of the present invention,
wherein 13 3/8 inch outside diameter conduits can be commonly used for
intermediate casing and can represent a conceptual point below which a large
selection of conventional apparatus are available for combinations of
subterranean pressures, apparatus diameters, and apparatus cross-sectional
areas.
However, with the use of outside diameter conduits above 13 3/8 inch, conduit
pressures applied to larger cross-sectional areas generally result in large
forces
that limit the availability of conventional apparatus.
[000244] The construction method embodiment (CS8) of the present invention
provides a
secondary barrier (148), that can support conduits and space arrangements
usable for selectively controlling pressurized subterranean fluid-mixture flow
streams, should the primary barrier conduits (149) fail. For example, within
the
hanger and packer arrangements of Figures 3, 6 or 12 or the chamber junctions
of Figures 59-62, 66-67 and 71, wherein pressures applied across large cross-
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sectional areas are controllable with conduits (150) usable as solid or
conduit
type connectors to secure conduit assemblies, with large cross-sectional
areas, to
act as pressure equalization passageways for preventing application of
pressure
across large cross-sectional areas. In addition, these large cross-sectional
areas
can act as pressure relief passageways, in the event of a primary barrier
(149)
breach, to limit pressures placed on the secondary barrier by, for example,
connecting the conduits to a subterranean formation with a fracture gradient,
that is less than the secondary barrier, to form a subterranean strata
pressure
relief mechanism.
[000245] The smaller diameters and associated higher pressure ratings of
pressure
relieving conduits (150) of the construction method (CS8) can be usable with
plates, fluidly separating the passageway between conduits (149, 150) and the
inside diameter of the secondary barrier (148). Integral plates can be usable
to
reinforce and improve the pressure integrity of the large diameter secondary
barrier (148), with the pressure relief conduits (150) communicating fluid
pressure to pressure relief flow controlling devices, in the event of a
primary
barrier breach to a pressure absorbing reservoir or pressure equalization
mechanism to, in use, prevent breaching the secondary barrier prior to
repairing
the primary barrier.
[000246] Referring now to Figures 71, 72, 73 and 74, the Figures include a
manifold
crossover (23V) embodiment depicted in plan, elevation cross-sectional,
isometric projection and magnified detail views, respectively, with break
lines
showing removed portions in Figure 72 cross-section, along line W-W of Figure
71, projected to form the isometric view of Figure 73, with the portion within
detail line X magnified in Figure 74. The depicted manifold crossover (23V)
embodiment is adapted from the chamber junction manifold (23T) of Figures
54-58. The Figures illustrate a construction method (CS8) with an additional
concentric conduit (2D of Figure 71) shown as a dashed line, usable as a
secondary barrier to form a concentric passageway (24C) about primary
barriers.
As shown the primary barriers comprise the conduit (2C), forming a concentric
passageway (24B) about the concentric conduit (2B), which forms an
intermediate concentric passageway (24A) about the concentric conduit (2A),
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which surrounds the intermediate concentric passageway (24) disposed about
the innermost conduit (2) and innermost passageway (25). The upper ends (90)
of the conduits are shown engagable with concentric conduits of a single main
bore while the lower ends (90) are shown engagable with, for example, conduits
of a junction of wells or other conduits of a single main bore, such as that
depicted in Figure 68.
[000247] The innermost upper end concentric conduits (2, 2A) can engage with
the
chamber (41) junction (43) forming lower end exit bore conduits (39) that can
fluidly communicate through a radial passageway (75) with the intermediate
concentric passageway (24) disposed about the innermost conduit (2). The
outermost concentric conduits (2B, 2C), fluidly separating concentric
passageways (24A, 24B), can transition to lower end fluidly separated radially
disposed pressurized fluid communication conduits (150).
[000248] As demonstrated in Figures 3, 6, 9-14 and 17-73, embodiments of the
present
invention thereby provide methods and manifold string (70, 76) arrangements of
manifold crossovers (23), valves (74), flow control devices (61) and
controlling
and/or measurement lines (79) that can be usable in any configurable
arrangement and placeable within a single main bore. and/or orientated to
selectively control pressurized fluid mixture flow streams of one or more
substantially hydrocarbon and/or substantially water wells from a single main
bore, during well construction and/or operations..
[000249] Referring now to Figure 74, the Figure depicts an elevation view
cross-sectional
slice through subterranean strata of a liquid underground cavern storage and
surface brine pond arrangement. The Figure shows concentric conduits (2, 2A)
passing through a passageway through subterranean strata (52), comprised of
casings and a strata bore forming a chimney above the cavern with walls (1A),
that are formed in a salt deposit (5). The conduit strings are usable to
transfer
brine to and from a pond for storage and displacement of the fluids to and
from
the cavern; wherein, after initial dewatering of a cavern, conventional
practice is
to only displace stored liquids with brine.
[000250] Surface and subterranean components, comprising the passageway
through
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subterranean strata (52) extending to a salt deposit (5), are later described
for a
conventional solution mining design (CM3 of Figure 80) and a gas storage
conventional completion design (CM4 of Figure 79).
[000251] Storage fluids can be injected (31) into the upper space within the
cavern walls
(1A) to displace (34) brine from the lower end space, below a substantially
water interface (117) to a brine pond (152) or other brine storage facility,
such
as another underground storage cavern.
[000252] In comparison, conventional practice may involve storage of saturated
brine
within an underground cavern after liquid storage displacement. However,
brine generation for displacement (1T) during simultaneous solution mining and
storage operations (15 of Figures 76, 80 and 81) with, for example, storage of
liquids in a brine and storage reservoir cushion and with stored brine
functioning
as an interface in u-tube fluid communication, with brine at the lower end of
a
gas storage cushion of a brine and storage reservoir, are not common
practices.
[000253] Surface pumps and motor arrangements (116), with surface manifolds
(155)
comprising conduits and valves, can be usable for operating injection or
extraction from the spaces within the cavern walls (1A), a brine pond (152),
or
other storage facility. The Figure illustrates the use of a transfer conduit
(153),
in communication with the pumps and motors (116), for extracting fluid from
the brine pond (152). In addition, Figure 74 shows the surface pumps and motor
arrangements (116) in communication with a storage operations conduit (154),
usable for displacing stored fluids.
[000254] Storage fluids can be displaced (34) from the upper end space, within
the cavern
walls (1A), by injecting (31) brine into the lower end space below the
substantially water interface (117), from a brine pond (152) or other brine
storage space, through the surface manifolds (155) pumps and motors (116).
[000255] Referring now to Figures 75, 76, and 80-83, the Figures describe
embodiments
(IT, 157) of the present invention, wherein storage caverns (158) are fluidly
engaged with brine reservoirs (159), via a u-tube like conduit arrangement,
wherein both comprise brine and storage reservoirs (158, 159). The brine
reservoirs (159) can be usable for brine generation during operation of a
storage
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cavern (158) product displacement and brine storage operation, until the brine
reservoir (159) and/or storage cavern (158), when under saturated brine is
produced, reaches their maximum effective stable diameter; after which, the
caverns (158, 159) can be usable for fully saturated brine and/or product
storage
at depths associated with the maximum effective diameter.
[000256] Brine reservoirs (159) can be usable to improve net present value
economics of
large salt cavern storage developments by providing continuous brine
displacement fluid during brine reservoir (159) solution mining operations (1,
1S), for product displacement operation of an underground storage cavern
(158),
or product displacement of a storage cavern (158) under saturated brine to a
brine reservoir (159). Thereafter, brine and storage reservoirs (158, 159) can
be
interchangably used as storage caverns (158) or brine generating caverns (159)
usable with under saturated or fully saturated brine fluids, for separating
storage
of substatiantially water brine fluids with substantially hydrocarbon fluids
of
differing demand cycles, for example, crude oil, diesel and/or gasoline from
an
opposite demand cycle from, for example, natural gas.
[000257] Embodiments of the present invention (1T) can be usable with other
apparatus
(for example 21, 23, 23F and 70R of Figure 80) and methods (for example CO3,
CS4, C06 and C07 of Figures 80 and 81) to selectively access fluids between a
plurality of fluid interfaces (117 and/or 117A) for providing selective
accessibility to various differing specific gravity products, that can be
stored
within a single or a plurality of underground brine and storage reservoir salt
caverns.
[000258] Figure 75 depicts a diagrammatic elevation cross-sectional view of a
slice
through subterranean strata depicting a method embodiment (11) for operating a
storage cavern (158) with brine from a subterranean brine reservoir (159). The
Figure illustrates a u-tube like conduit arrangement between wells, with
heavier
brine at the lower end of both caverns and located below a substantially water
interface (117) transferred from one cavern to the other with working pressure
(WP1 to WP2). Dashed lines within the caverns represent the notional u-tube
like arrangement, with brine or another heavier storage fluids gravity
separated
below lighter fluids, with substantially water (117) and/or fluid (117A)
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interfaces that can be stored in the upper cushion portion of each brine and
storage reservoir salt cavern (158, 159).
[000259] A brine reservoir (159) is solution mined (1), and/or usable for
storage while
being solution mining (1S), to produce brine, that can be expelled (34)
through a
disposal conduit (153A) until, for example, the cavern reaches a desired size
to
operate an underground storage cavern (159). The brine is produced from the
bring reservoir (159) through a transfer conduit (153) and u-tube arrangement,
with the salt saturation level, of continuous brine provision, dependent on
the
temperature, pressure, volume and residence time of water injected (31)
through
the feed conduit (156) and into the brine reservoir (159), and in this
instance,
falling to the substantially water interface (117).
[000260] During solution mining (1), the water can be provided through the
feed conduit
(156) with any fluid, for example, compressed air, nitrogen, diesel, salt
inert
and/or other storable products. The water can be injected (31) through the
feeding conduit (156) into the cushion above a substantially water interface
(117) or fluid interface (117A) of the brine reservoir (159), during combined
mining and storage operations (1S), to exert working pressure (WP1) on the
interface (117 or 117A), which, through the u-tube arrangement, expels (34)
the
brine through a disposal conduit (153A) or injects (31) the brine through the
transfer conduit (153), to the lower end of the underground storage cavern
(159),
which exerts working pressure (WP2) on the fluid interface (117 or 117A) to
displace (34) stored fluid from the underground storage cavern (158) to a
storage operations conduit (154) or pipeline.
[000261] Working pressures (WP1, WP2) can depend upon the hydrostatic and
dynamic
pressure heads for stationary and moving fluid columns within the caverns,
with
various possible saturations of brine and liquids or gases that are storable
within
either cushion, above and below either substantially water or fluid interfaces
(117, 117A).
[000262] If compressible fluids, for example, air, nitrogen or natural gas,
are used to
apply working pressure (WP1), then subsequent release of the compressed fluid
can be usable to drive, for example, turbines or pneumatic motors, which can
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further usable to aid storage operations. Heat transfer (160) from compression
of the fluids can be further usable to heat the cavern and partially offset
temperature reductions associated with solution mining and/or compressed fluid
expansion.
[000263] If one or more lighter specific gravity fluids and/or stored products
are placed
within a cavern, fluids will gravity separate, given sufficient residence time
from
the heavier brine, u-tubed between the lower ends of both caverns (158, 159),
and form one or more lighter specific gravity fluid interfaces (117 or 117A)
from, for example, separated fluids of a pipeline pigging operation.
[000264] Conventional two string completions (CM5 of Figure 81) can be usable
to
operate single substantially water interface (117) arrangements within each
cavern. Alternatively, the two string completions can be usable to operate
manifold strings (70 of Figure 80) with concentric manifold strings (2, 2A of
Figure 80), instead of the single strings (2), as shown, to selectively access
a
plurality of gravity separated fluids between a plurality of fluid interfaces
(117
and 117A), with manifold crossovers (21 and 23 of Figure 80) forming part of a
manifold string within either cavern (158, 159).
[000265] Water can be injected (31) into the mining and/or storage operations
conduit
(156) of the brine reservoir (159) with a salt inert fluid, such as nitrogen,
hydrocarbon gas or diesel, that can be placed and floated above the injected
water to protect the final cemented casing shoe. The water can be used to
produce brine through salt dissolution, with methods similar to those
described
in Figures 76, 80 and 81, for displacement of the upper end cushion of the
storage cavern (158) during storage retrieval operations.
[000266] Gas storage caverns, for example, may retrieve (34) stored gas from a
cavern
(158) with significantly less temperature drop by displacing to adjust volume,
so
as to maintain compressed gas pressure with brine produced from a brine
reservoir (159) through the connecting conduit (153) u-tube, while filling
(31)
the brine reservoir with water to produce additional brine.
[000267] For liquid or gas storage, brine displacement can be usable during
demand
cycles, while solution mining a brine reservoir. Brine from the storage cavern
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(158) can be disposed to, for example, the ocean with subsequent re-filling of
the cavern with stored product, while salt dissolution or solution mining
continues within the brine reservoir (159), Alternatively, brine can be
displaced
back to the brine reservoir, displacing the storage cushion (1S) and/or under
saturated brine in the brine reservoir.
[000268] If compressed air or nitrogen was used to u-tube brine from a brine
reservoir
(159) into the expel (34) fluids, such as gas from a storage cavern (158),
then the
compressed air or nitrogen in the brine reservoir (159) can be usable to drive
a
turbine or pneumatic motor to aid storage operations and can be released to
the
atmosphere.
[000269] A brine reservoir can be usable to form brine continuously during
displacement
operations, if water is the displacement fluid, with the salt concentration
levels
being a function of residence time, pressures volumes and temperatures.
Partially saturated brine can be usable to minimize salt dissolution in a
storage
cavern (158) during combined solution mining, and storage operations (1S),
provided there is sufficient effective diameter available for such under
saturated
displacements prior to reaching a critical cavern stability diameter.
[000270] Storing (31), for example, crude oil, gasoline or diesel in the right
side brine
cavern (159) upper end cushion to u-tube brine, that is partially and/or fully
saturated, to the storage cavern (158) for displacing gas during high winter
seasonal demand and lower seasonal crude oil, gasoline and/or diesel demand,
may be followed by subsequent storage cavern (158) dewatering, with
compressed natural gas, during spring or summer seasonally low gas demand,
by u-tubing the saturated or partially saturated brine back to the brine
reservoir
(159) for displacing crude oil, gasoline and/or diesel during the spring or
summer seasonally high demand cycle.
[000271] Displacement of partially saturated brine between salt caverns can be
usable
until reaching a maximum effective diameter for salt cavern stability at
relavent
subterranean depths within the brine reservoir (159) usable to store brine
and/or
products and the storage cavern (158) usable to store brine and/or products.
One
or more fluid interfaces (117A) may be present between products of differing
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specific gravities, effectively floating on top of each other. Fluids, between
differing fluid interfaces, can be accessible with manifold strings (70 of
Figure
80).
[000272] Referring now to Figure 76, the Figure depicts a diagrammatic
elevation view
cross-sectional slice through subterranean strata of a method embodiment (IT)
for operating a storage cavern with a subterranean brine reservoir. The Figure
shows a u-tube arrangement, similar to Figure 75, that can be usable to
operate
the storage cavern (158) with brine produced by solution mining (1) and
combined operations (1S) within the brine reservoir (159) with one of two
conduits (2) in each cavern (158, 159). Pumps (116), turbines, motors and
valved manifolds (155) are shown and can be usable for injecting fluids into
and
urging fluids from a salt cavern.
[000273] Various solution mining (1) methods, comprising injecting water to
control a
substantially water interface (117), usable to extend the cavern roof from a
fixed
diameter upward (1B to 1C to 1A), increasing the cavern diameter after
solution
mining by a lesser diameter upward (1B to 1C to 1A), or combinations thereof,
can be usable to form intermediate cavern shapes (147) usable for combined
operations (1S) of combined solution mining (1) and storage, prior to reaching
the final design cavern walls (1A) at the maximum effective diameter for salt
cavern stability.
[000274] Combined storage and solution mining operations (1S) can occur from
increasing the cavern diameter after solution mining a lesser diameter upward
(1B to 1C to 1A), for example, comprising injecting (31) water from a supply
conduit (156) into the upper end of the cavern below the upper depicted
substantially water interface (117) or, for example, from a fixed diameter
upward (1B to 1C to 1A) with injected (31) water falling to the lower depicted
substantially water interface (117). The combined operations (1S) can be
usable
to produce brine through salt dissolution, occurring between the intermediate
cavern walls (147) and the final cavern walls (1A), to operate the storage
cavern
(158) with fluid displacement, by producing (34) brine through the brine
reservoir (159) lower end inner conduit (2), transfer conduits (153) and
surface
manifold (155) with the use of surface pumps (116), usable to inject the brine
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into the lower end of the storage cavern (158), through its inner conduit (2),
floating stored product from the cavern above the substantially water (117) or
fluid interface (117A). The working pressures (WP2) and pumping (116) can be
usable to move the storage cavern (158) substantially water (117) or fluid
(117A) interface upward, selectively controlling the working pressure (WP1)
with the valve tree, to produce (34) stored fluids from the upper end of the
storage cavern (158).
[000275] The described method can be reversible by arranging flow from the
storage
cavern (158) to the brine reservoir (159), wherein product may be moved with
transfer (153) or production (154) conduits from the upper or lower end of
either
cavern to the other. Stored product from the storage cavern (158) upper end is
generally usable as a salt inert solution mining cushion at the upper end of a
brine reservoir (159), or brine in the storage cavern (158) lower end can be
returned to the brine reservoir (159) lower end.
[000276] If, for example, compressed air from a wind turbine or other
compressible
fluids, such as nitrogen from a nitrogen generator, are used to displace brine
from a reservoir (159) in the displacement operation of a storage cavern
(158),
during storage cavern (158) product re-injection (31) the compressed upper end
brine reservoir (159) fluids can be releasable to the atmosphere and/or usable
to
drive, for example, a surface pneumatic motor (116) or to process turbines
through a surface manifold (155) to aid storage operations.
[000277] Where appropriate, various operation methods, between the brine
reservoir
(159) and storage cavern (158), can use subterranean heat transfer (160) in
storage operations to, for example, maintain temperatures in a gas storage
cavern (158), that was displaced with brine thermally heated by the
subterranean
strata over a period of residence in a brine reservoir (159).
[000278] Figure 77 depicts an example of a graphical representation of the
conventional
concept of increasing usable working gas volume from the lower end of the
vertical axis upward, over an increasing period of years on the horizontal
axis
from left to right, resulting from subterranean heat transfer (160) to an
underground gas storage cavern. The Figure shows that due to the lower
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temperatures of water used in solution mining over a period of years, and the
chemical process of salt dissolution, the strata around a cavern is cooled
below
its natural state, and, for this particular example, requires a number of
years to
return to its original temperature.
[000279] While conventional practice for retrieving underground liquid storage
can use
brine displacement, as described in Figure 74, it is not conventional practice
to
use brine displacement to retrieve gas stored underground in a salt cavern.
Hence the Figure 77 graph is usable to explain how the temperature of the
cavern can affect the underground salt cavern gas working volumes, and why
brine displacement can be usable to increase working volume during earlier
years with lower cavern temperatures, when, for example, subsurface safety
valves are usable to contain compress gas (CS4 of Figure 80, CM5 of Figure
81).
[000280] Conventional methods for using working gas volume require increasing
volume,
by expanding compressed gas, to extract it from a cavern with the ideal gas
equation [P1*V1)/T1.(P2*V2)/T2], stating that as the volume increases at a
relatively constant pressure, a proportional temperature drop is realized. As
conventional gas storage practices expand compressed gases during retrieval,
the initial temperature imparted on the compressed gas from a cold cavern
shortens the withdrawal period, because the temperature decline of the
compressed gas starts from a lower temperature. As the cavern heats up over a
number of years, it transfers heat (160) to the compressed gas within causing
withdrawal periods to lengthen by starting from a higher compressed gas
temperature, thus increasing usable working gas volume as shown in the Figure
77 graph. Because gas starts decompression from a higher temperature in later
years, more of the cavern volume can be usable before reaching the limiting
temperature of associated equipment and the final cemented casing shoe,
associated with gas decompression.
[000281] Gas storage embodiments (1T of Figures 75, 76 and 80-83) of the
present
invention increase the withdrawal period and usable working gas volume within
a cold cavern by displacing compressed gas with brine in a manner similar to
the
conventional method for underground stored liquid retrieval. This is explained
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by the ideal gas equation [(P1*V1)/T1=(P2*V2)/T21 relationship, which states
that retrieval at a relatively constant pressure and volume causes a
relatively
constant withdrawal temperature. Hence the temperature limits of associated
equipment and the casing shoe are not reached as quickly, dependent upon the
filling rate of brine and extraction rate of gas, and the usable working gas
volume increases in the earlier years when caverns are cold.
[000282] In instances where volumes cannot be maintained through brine
injection during
extraction of gas from storage and the cooling effects of gas expansion are
present, withdrawal periods are at least increased thereby increasing the
usable
working gas volume.
[000283] Figure 78 depicts an exemplary graphical representation of the
conventional
concept of working volume usage during short (161) and longer (162) demand
cycles, with the vertical axis depicting increasing percentages of usage
upwards,
and the horizontal axis illustrating an increasing number of weeks over a
yearly
period, from the left to right. The Figure shows that in the conventional
storage
operations of this example, a shorter weekly demand leveling requires
approximately 10% of the gas cavern working volume, while seasonal swings
represent full working volume usage.
[000284] During initial years of gas storage in instances where salt deposits
are relatively
shallow with associated low temperatures, especially after years of solution
mining and salt dissolution, short term gas demand leveling requires only a
portion of working volume and is less affected by low initial cavern
temperatures. However, longer term season supply is significantly affected by
lower cavern temperatures because all the working volume is needed, and there
is less working volume available, as shown in Figure 77. As shallow salt
caverns are typically at lower temperatures than deeper depleted gas storage
sandstone reservoirs, conventional gas supply and demand typically rely on
salt
caverns for short-term peak gas demand leveling and depleted sandstone gas
reservoirs, less affected by temperature limitations, for the season demand
swings.
[000285] Methods (1T of Figures 75, 76 and 80-81) of the present invention can
be usable
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to extend gas withdrawal periods, thus increasing working gas volumes
available for seasonal demand through brine displacement, which can remove
the need for a sunk cost gas cushion gas to resist salt creep and to maintain
salt
cavern roof and wall integrity. Increased working gas levels thus provide a
means for large gas tight salt cavern storage facilities to supply seasonal
demands, conventionally restricted to less than gas tight depleted sandstone
reservoir storage facilities, wherein the gas tight integrity of cap rock and
spill
points cannot be tested.
[000286] Referring now to the left side cavern and conventional well of Figure
80 and
Figure 79, the Figures depict the conventional completion method (CM4) of
Figure 79 usable after, for example, the conventional solution mining (1)
method (CM3) of the Figure 80.
[000287] Alternatively, the conventional configuration (CM3 of Figure 80) is
usable for
both solution mining and conventional liquid storage operation, with brine
displacement practices similar to that of Figure 74.
[000288] In conventional liquid storage wells, similar to that of Figures 74
and 80, where
the stored products do not pose a significant evaporative or expansion escape
risk (e.g. crude oil or diesel), generally a subterranean valve (74 of Figure
79) is
not present and a dewatering string (2 of Figure 74 or Figure 80 left side
well)
remains placed through the production casing (2A of Figure 74, Figure 80 left
side well), with product injected or extracted indirectly through the
passageway
between the dewatering string and the production casing, and the brine
extracted
or injected through the dewatering string. Stored liquid products generally
displace brine from the space within the cavern walls (1A) during storage or
can
be retrieved from storage by direct injection of brine from a pond or storage
facility, through the dewatering string, to float the lower specific gravity
product
out of the cavern, as shown in Figure 74.
[000289] Figure 79 depicts a diagrammatic cross-sectional slice elevation view
through
subterranean strata of the conventional completion method (CM4) for operating
a gas storage salt cavern. The Figure shows a dewatering string (2) as a
dashed
line placed through a subsurface safety valve (74).
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[000290] The free hanging leaching strings (2, 2A of Figure 80 left side well)
have been
removed and a completion, comprising production casing (2), that can be
engaged with a production packer (40), further engaged to the final cemented
casing (3), is secured at upper end to a wellhead (7) and valve tree (10A)
with
surface valves (64), to control injection and extraction of fluids, that have
been
installed.
[000291] In instances of expandable or volatile fluid storage, for example
compressed gas
storage, a fail safe shut subterranean valve (74) can be generally placed in
the
production casing (2), through which a dewatering string (138 shown as a
dashed line) is placed. Expandable or volatile fluids can then be used to
displace brine from the cavern with indirect injection (31) through the
passageway, between the dewatering (138) and production casing (2), taking
brine, expelled (34) from the cavern, through the dewatering string (138);
after
which, the dewatering string (138) must be stripped or snubbed out of the well
in a relatively high risk operation, where personnel are in close proximity to
pressurized barriers, to allow the fail safe safety valve (74) to function.
[000292] If the cavern is cold from, for example, after solution mining, the
working gas
volumes will increase as subterranean thermal transfer heats the cavern, as
described in Figure 77. Conventional practice typically does not place brine
back in the cavern, leaving it dry to avoid high risk stripping and snubbing
operations, necessary for removal of a dewatering string from across the
subsurface safety valve. Conventional dual conduit completions, such as those
shown in Figure 81 can be, however, usable to provide a dewatering string with
a subsurface safety valve.
[000293] Conventional methods (CM3 of Figure 80 and CM4) for constructing salt
caverns and initializing gas or volatile liquid underground storage are labor
intensive and potentially hazardous, taking a number of years to complete
before
realizing a return on investment. Additionally, conventional practice requires
a
significant volume of compressed cushion gas, representing a sunk cost, that
must be left in the cavern to resist salt creep and degradation of the cavern
walls
and roof.
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[000294] Figure 80 depicts a diagrammatic cross-sectional slice elevation view
through
subterranean strata of a method embodiment (IT) for operating a storage cavern
with a subterranean brine reservoir. The Figure shows a conventionally
constructed (CM3) left side well that can be usable for solution mining and/or
liquid storage that is engagable to a right hand well (CS4) with apparatuses
(21,
23, 23F, 70, 70R) and methods (CO3) of the present inventor that can be usable
for dewatering and selective access to liquid and/or gas storage, to replace
the
conventional gas storage arrangement of Figure 79 for example, during
combined solution mining (1) and storage operations (1S). The wells can be
formed with conductors (14), intermediate casings (15), and final cemented
casings (3) sealed with a cavern chimney, with a casing shoe (16) below which
a
strata passageway (17) is bored and strings (2, 2A) are placed for solution
mining operations.
[000295] In the convention solution mining (1) method of the left side well
(CM3), a free
hanging inner string (2) is placed within an outer free hanging string (2A),
which can be adjusted with the use of a large hoisting capacity rig during the
process to reposition the point at which fresh water enters the solution
mining
region of a salt deposit (5), and/or to provide improved sonar measurements
than
are possible through casings (2, 2A). A salt inert cushion of nitrogen or
diesel is
generally displaced between the final cemented casing (3) and outer leaching
string (2A) to control the substantially water interface (117) and to protect
the
final cemented casing (3) shoe (16).
[000296] Example apparatuses (21, 23, 23F, 70, 70R) and methods (CO3) of the
present
invention in the right side well (CS4) provide access through crossovers (21,
23)
at the lower end of the inner (2) and outer (2A) strings to access various
regions,
within intermediate cavern volume (147) usable for combined solution mining
(1) and storage (1S) and for final (1A) cavern walls.
[000297] Either the right (CS4) or left side (CM3) wells can be usable as a
brine reservoir
(159) or an underground storage cavern (158), within the method (1T) for brine
and storage reservoirs (158, 159).
[000298] Solution mining and brine generation (1) can be usable with injected
potable
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water, pond water, ditch water, sea water, and/or other forms of water,
generally
termed fresh water due an unsaturated salinity level compared to the produced
salt saturated brine. The water can be injected through the innermost
passageway (25) or the intermediate concentric passageway (24), between the
inner (2) and outer (2A) free hanging conduit strings, or vice versa, using
direct
or indirect circulation with a cushion. The cushion generally comprises diesel
or
nitrogen. Then, the water can be forced into an additional intermediate
concentric passageway (24A), between the outer conduit string (2A) and final
cemented casing (3), for the left side well (CM3), or the water can be forced
through a passageway (24, 25) of the right side well (CS4) and allowed to
float
up to the final cemented casing shoe, to control the water interface (117),
wherein an initial solution mined space can be formed for insoluble strata to
fall
through a substantially water fluid to the cavern floor (1E).
[000299] Generally, caverns are solution mined (1) from the bottom up by
mining a space
(1B) with a water interface (117). Then, the water interface (117) can be
raised,
repeatedly, to create increasing volumetric spaces (1C and 1D) with water
insoluble strata falling through fluids and raising (1E, IF, 1G) the cavern
floor,
while continuously injecting (31) fresh water and extracting (34) saturated or
nearly saturated salt brine, dependent upon the residence time, pressure,
volume
and temperature conditions of the salt dissolution process.
[000300] The method (CO3) can be usable to simultaneously perform storage and
solution
mining operations (1S) by first forming an initial space within cavern walls
(1B,
IC, 147) with direct circulation of fresh water through the innermost
passageway (25), and with salt saturated brine returned through the concentric
passageway (24), using the lowest water interface (117) above the lower end of
the outer string (2A). Alternatively and indirectly, the brine can be returned
from the concentric passageway (24) to the innermost passageway (25), using
the manifold crossover (23) flow diverter (21), at selected depths,
corresponding
to various fluid interfaces (117), during which time a salt inert fluid
cushion can
be periodically injected through one of the passageways (24, 24A, 25) and
trapped under the casing shoe (16). Various initial cavern volume shapes can
be
formed with direct or indirect circulation and adjustment of the salt inert
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cushion controlling the water interface selectively changed using a manifold
crossover (23) and flow diverter (21), for the right hand well (CS4), or the
additional concentric passageway (24A) for the left hand well (CM3), to form a
volume (147) with lesser effective diameter and volume than the final cavern
wall (1A), for simultaneous storage and solution mining operations (1S).
[000301] Various initial cavern shapes (147) can be formable by controlling
water
residence time against the roof, sides and bottom of a cavern at the various
salt
dissolution rates to simultaneously produce brine from a brine reservoir
cavern
(159), while fluidly displacing and operating an underground storage cavern
(158) with less than fully saturated brine, if the maximum effective cavern
diameter of the walls (1A) has not been solution mined or fully saturated the
brine after reaching the final cavern wall (1A) effective diameter.
[000302] The method (11) can be usable, for example, with gas storage within
gas tight
salt caverns to increase the number of working volume turn-overs and for
profitability of short term trading, using an intermediate cavern volume
(147),
until reaching a cavern volume sufficient for seasonal near-full capacity
working
volume swings.
[000303] The left side well (CM3) is usable, for example, as a brine reservoir
(159), that
can be engaged, through a u-tube like arrangement, to the lower end right side
well (CS4) storage cavern (158) for combined storage (1S) and solution mining
(1) operations, with a short term trading volume of gas within an upper end
cushion, that can be controlled by a valve manifold crossover (23F) above the
fluid interface (117). During combined storage and solution mining operations
(1S), water can be usable to displace short-term gas trading volumes with
subsequent gas product displacement, which can force brine from the cavern
before resuming solution mining or during later phases. When the effective
diameter of the walls (147) is approaching its maximum (1A), brine, from the
brine reservoir (159), can be divertible through the u-tube like arrangement
to
the lower end of the underground storage cavern (158) for pressure assisting
the
extraction of the short-term and longer term seasonal trading volumes of gas.
[000304] The well construction method (CS4), with manifold crossover (23F) and
flow
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diverters (21), can be usable, for example, to perform both solution mining
and
storage operations (1S) without rig intervention, which is generally necessary
to
adjust the outer leaching string (2A) of conventional wells (CM3) or to
provide
a dual well valve dewatering string arrangement (CM5 of Figure 81). A smaller
cavern volume, formed by first solution mining a smaller diameter cavern
axially upward at the faster dissolution rate of the cavern roof, can be
usable to
form a storage cushion volume (147). Thereafter, the water interface can be
lowered by the volume of stored product during, for example, weekend lower
gas usage period which displaces the brine. Then, the stored product can be
released during daily peak demands, as fresh water is injected to solution
mine
the cavern walls to a larger diameter, from the bottom up, and wherein stored
cushion product extraction and associated pressures are aided by fresh water
injection.
[000305] Figure 81 depicts a diagrammatic cross-sectional slice elevation view
through
subterranean strata of a method embodiment (1'1), with conventional dual well
valve string arrangements (CM5) usable for operating a storage cavern (158)
with brine from a subterranean brine reservoir (159). The Figure depicts
smaller
cavern cushion storage spaces (147), corresponding to increasing diameters
which are less than the maximum effective diameter for cavern stability,
solution mined (1) first for the purpose of simultaneous storage operations
(1S),
and with a working pressure (WP) usable to selectively control the
substantially
water interfaces (117), during enlargement of the cavern walls (1B, 1C, 1D).
Various methods for shaping a cavern can be usable including, for example,
notionally vertical cavern walls methods (C07) or inward sloping cavern wall
methods (C06), providing more roof support and allowing a lower minimum
cavern pressure.
[000306] Either cavern can be usable as a storage cavern (158). The remaining
cavern can
be usable as a brine reservoir (159) for solution mining with water supplied
through a feeding conduit (156) and valves (64) of a valve tree (10). The
brine
can be expelled through a disposal conduit (153A) or a transfer conduit (153)
forming a u-tube like brine transfer arrangement between cavern lower ends,
with product supply through a supply conduit (154) or pipeline to form an
upper
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end cushion that can protect the final cemented casing (3) shoe (16). Escape
of
the upper end cushion can be controlled by subsurface safety valves (74).
[000307] Referring now to Figures 82 to 83, various diagrammatic plan view
embodiments (157) of underground storage cavern (158) and subterranean brine
reservoir (159) arrangements usable with brine and storage reservoir
operations
methods (1T) and combined solution mining and storage operations (1S),
depicting cavern configurations usable to provide salt deposit pillar support,
according to the product stored and working pressure variations with cavern
exclusion zones (1Z).
[000308] Conventional practice is to space caverns, that are mined for their
salt, in close
proximity, and to potentially use such caverns for solid waste disposal, to
remove pressurization requirements. Such close proximity caverns are stable
because the hydrostatic pressure of a saturated salt column is generally at
least
equal to the strata overburden pressure acting to plastically deform the salt
deposit. Additional pressure applied through the valve tree and wellhead can
over pressure the cavern to prevent degradation of the cavern walls and roof.
[000309] Pressure integrity of a cavern generally depends upon the fluid being
contained
with liquid pressure integrity generally greater than, for example, gas tight
integrity within the same cavern, with the capillary and cohesive properties
of
liquid greater than gas attempting to escape through micro annuli and porous
or
permeable spaces with the strata.
[000310] Brine reservoirs (159), using an upper end liquid cushion with water
and having
brine below their substantially water interface, are placeable in closer
proximity
than, for example, underground storage caverns (158) with gas product, wherein
a higher pressure is maintainable within a liquid storage cavern than a
gaseous
storage cavern, to maintain cavern stability.
[000311] Methods (1S, 1T) of the present invention can be usable for operating
a storage
cavern (158) with brine from close proximity liquid storage brine reservoirs
(159), engaged with stored product (154), and brine transfer (153) conduits to
storage caverns (158) arranged with larger cavern exclusion zones (1Z) and
associated with more salt deposit overburden pillar support between cavern
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walls (1A).
[000312] Various configurations and orientation arrangements can be usable
with the
depicted arrangements showing centralized liquid storage brine reservoirs
(159),
engaged with a supply conduit (154) or pipeline, and further engaged with
various other brine reservoirs (159) or underground storage caverns (158) that
require larger exclusion zones (1Z) for salt deposit pillar support, with
supply
(154) and transfer (153) conduits.
[000313] Water supply and brine disposal conduits are placeable centrally or
individually
for each cavern, for example, in an ocean environment where offshore platforms
exist above caverns, with water taken and brine disposed to the ocean during
solution mining.
[000314] Offshore ocean access via pipelines (153, 154) to each platform
and/or ship
access for loading and unloading of, for example, crude oil within a brine
reservoir (159) or storage cavern (158).
[000315] As demonstrated in Figures 75 to 76 and 80 to 83, embodiments of the
present
invention provide systems and methods for combined or simultaneous storage
and solution mining operation that can be usable in any configuration or
arrangement, including with various apparatus and methods that can be
placeable in the subterranean strata, onshore or offshore, and that can be
engaged with conduits carrying products to be stored, water for salt
dissolution,
or brine for selectively displacing stored product within another cavern or
the
cushion between the final cemented casing shoe and a substantially water
interface. These systems and methods can be further usable to form a
subterranean brine and storage reservoir with salt dissolution, wherein two or
more strings having a plurality of passageways and a valve tree can be usable
to
selectively operate or form one or more subterranean brine storage reservoirs,
with salt inert cushion fluid and water for associated operation of one or
more
other underground storage salt caverns, by selectively communicating fluids
between the caverns with pumping, compression and/or pressure equalization.
[000316] While various embodiments of the present invention have been
described with
emphasis, it should be understood that within the scope of the appended
claims,
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the present invention might be practiced other than as specifically described
herein.
