U.S. patent number 3,804,169 [Application Number 05/330,355] was granted by the patent office on 1974-04-16 for spreading-fluid recovery of subterranean oil.
This patent grant is currently assigned to Shell Oil Company. Invention is credited to Philip J. Closmann.
United States Patent |
3,804,169 |
Closmann |
April 16, 1974 |
SPREADING-FLUID RECOVERY OF SUBTERRANEAN OIL
Abstract
In a process for producing shale oil by circulating fluid
through a cavity that contacts a subterranean oil shale, the cavity
is extended laterally into both an injection well and a plurality
of surrounding productions wells and the fluid is circulated at a
rate causing the velocity within the cavity to decrease with radial
distance away from the injection well to a velocity that is too low
to transport relatively large particles of mineral solids.
Inventors: |
Closmann; Philip J. (Houston,
TX) |
Assignee: |
Shell Oil Company (Houston,
TX)
|
Family
ID: |
23289398 |
Appl.
No.: |
05/330,355 |
Filed: |
February 7, 1973 |
Current U.S.
Class: |
166/267;
166/272.1; 166/272.3 |
Current CPC
Class: |
E21B
43/281 (20130101) |
Current International
Class: |
E21B
43/00 (20060101); E21B 43/28 (20060101); E21b
043/24 (); E21b 043/28 () |
Field of
Search: |
;166/272,271,267,264 |
References Cited
[Referenced By]
U.S. Patent Documents
Primary Examiner: Brown; David H.
Attorney, Agent or Firm: Coryell; H. W.
Claims
What is claimed is:
1. A process of producing shale oil from a subterranean oil shale
which comprises:
extending a subterranean cavity that contacts the oil shale
generally radially throughout at least one well pattern that
contains more production wells than injection wells;
injecting a hot fluid that is adapted to interact with the oil
shale to yield shale oil into the cavity through at least one
injection well;
producing fluid inclusive of shale oil from the cavity through a
plurality of production wells;
coordinating the rates and velocities of said injections and
production of fluid to maintain both substantially equal rates of
outflow from a plurality of production wells around each injection
well, and a pattern of flow velocities within the cavity that
diminish with radial distance away from each injection well and
become too low to transport significantly large particles of solid
material into the production wells; and
recovering shale oil from the produced fluid.
2. The process of claim 1 in which the injected fluid is flowed
into contact with oil shale located above the cavity and is flowed
down along a generally vertical section of exposed oil shale.
3. The process of claim 1 in which an initial well pattern is
expanded by forming a generally radial extension of the cavity and
opening additional wells in the so-expanded cavity with said wells
being located in an arrangement that provides a plurality of
injection wells which are each surrounded by a plurality of
production wells.
4. The process of claim 1 in which the injected fluid includes at
least one slug each of a hot aqueous fluid and a hot nonaqueous
fluid.
5. The process of claim 4 in which the oil shale being treated
contains a heat sensitive mineral component and the rate of its
extraction is controlled by adjusting the volumes of said
alternating slugs of injected fluid.
Description
BACKGROUND OF THE INVENTION
The invention relates to producing shale oil components from a
subterranean oil shale formation. More particularly, it relates to
circulating a hot fluid through an areally extensive cavity that
contracts the oil shale so that the pattern of flow controls the
extent to which particles of mineral solids are fluid-transported
and avoids the plugging of conduits.
Many subterranean oil shale formations comprise nonporous solid
earth materials that are impermeable to fluids and contain more
inorganic components than organic components. When the organic
components are selectively removed by circulating a hot fluid into
contact with an oil shale, the materials remaining in the portions
of depleted oil shale (along the walls of a cavity or a fracture)
may have a bulk volume that is larger than the bulk volume of the
original oil shale. In the course of removing portions of the
organic components, the remaining inorganic components become
heated, thermally expanded, and pushed apart by invading portions
of fluid, so that they form a mass of liquid permeated solids that
is porous and has acquired a larger bulk volume. Such a volume
increase tends to cause the depleted materials to swell into and
close fractures, or to spall into and fill up cavities, unless the
roofs of the fractures or cavities are hydraulically lifted by the
fluid pressures within the fractures or cavities. Since the
particle sizes of these materials are normally rather small, the
permeability of the filled cavities is greatly reduced. A hydraulic
lifting within the fractures or cavities is disadvantageous in
creating a possibility of break through of highly pressurized fluid
to the surface and/or lifting the surface of earth formation into a
mound that may be ecologically undesirable and/or creating the
possibility of communicating with some other higher zone, such as
an aquifer, or the like actions that would be environmentally very
undesirable.
Where a subterranean oil shale contains or is interbedded with
water soluble minerals, such as nahcolite, trons, soluble halides,
or the like, those materials can be used to form a subterranean
cavern or cavity that contacts the oil shale. Such a cavity can be
formed by solution-mining, and can be used to provide both a path
through which a hot fluid can be circulated to contact oil shale,
extract shale oil, and provide space in which some or all of the
increased bulk of the depleted oil shale components can be
accommodated. However, such a solution-mining-preceded recovery
process may have a significant disadvantage with respect to
postponing the recovery of oil pending a relatively long and
expensive mining operation in order to provide a cavity that is big
enough to accommodate a significant portion of the depleted oil
shale.
Where a subterranean oil shale contains or is interbedded with
heat-sensitive carbonate mateirals, such as nahcolite, dawsonite,
or the like, a thermal conversion of those materials can be
utilized to reduce the bulk of the depleted materials for the
extraction of shale oil. In such a procedure, the hot fluid which
is circulated into contact with the oil shale to effect a pyrolysis
and/or extraction of shale oil components is an aqueous hot fluid
(such as steam and/or hot water) that converts the heat-sensitive
carbonate materials to water soluble materials. This dissolves and
removes a portion of the inorganic components of the oil shale. It
may reduce the bulk volume of the spent oil shale residue to an
extent such that the rate of fill-up of a cavity may be less than
the rate of material removal and thus may cause the cavity to grow
in size rather than become filled in with depleted oil shale
materials. However, serious problems may be encountered when such a
hot aqueous fluid is circulated through a cavity in contact with a
subterranean oil shale. For example, in tests in which steam was
flowed into and along the walls of a well so that steam contacted
an upper portion of the subterreanean oil shale at a temperature of
about 500.degree.F (i.e. a temperature sufficient to cause both a
relatively rapid pyrolysis of the oil shale kerogen and a
heat-induced decomposition of heat-sensitive carbonate components
of the oil shale) and the resultant aqueous and organic liquids
were withdrawn from a lower level within the oil shale, the
production conduits rather quickly became severely plugged with
large and small particles of organic and inorganic solid
materials.
SUMMARY OF THE INVENTION
The present invention relates to producing shale oil from a
subterranean oil shale. A cavity that contacts the oil shale is
extended into and preferably beyond at least one well pattern that
contains more production wells than injection wells. A hot fluid
that is adapted to interact with the oil shale to yield shale oil
is injected into the cavity through the injection well. Fluid that
contains shale oil is produced from the cavity through a plurality
of production wells. The rates and velocities of the flow of fluid
within the cavity are controlled to provide both substantially
equal rates of outflow from the plurality of producing wells
surrounding each injection well and a flow velocity within the
cavity that diminishes with radial distance away from each
injection well and becomes too low to transport significantly large
particles of solid mineral materials before reaching the
surrounding production wells. Shale oil is recovered from the
produced fluid.
DESCRIPTION OF THE DRAWING
The drawing is a schematic illustration of a portion of the
subterranean oil shale containing wells through which the present
invention is practiced.
DESCRIPTION OF THE INVENTION
As used herein, the term "cavern" or "cavity" refers to any
relatively solids-free opening such as a cave, void, tunnel,
borehole, or highly permeable mass of rubble or interconnected
fractures, etc. Such a cavern "contacts a oil shale" when a portion
of the oil shale forms at least a portion of the wall so that there
is fluid communication between the interior of the cavern and the
oil shale. The term "heat-sensitive carbonate mineral" refers to a
carbonate mineral that decomposes relatively rapidly at a
relatively low temperature (such as between about 250.degree.F and
700.degree.F) to yield fluid products such as carbon dioxide and
water. Examples of heat sensitive carbonate minerals include
nahcolite, dawsonite, trona, and the like, which usually contain
carbonate and/or bicarbonate compounds or groups.
The drawing shows the application of the present process to a
subterranean oil shale formation, which is interbedded with a
horizontally extensive layer of water-soluble mineral, such as
nahcolite layer 2.
The oil shale, to which the present process is applied, is
preferably one that contains a significant amount of heat-sensitive
carbonate. Such an oil shale may contain sections of vertical
intervals of as much as several tens of feet thick, which are
substantially devoid of heat-sensitive and/or water soluble
materials. In such a heterogeneous oil shale formation, in the
course of application of the present process, such heat-sensitive
or soluble minerals are converted to fluids and/or dissolved and
removed so that portions of the oil shale become incompetent and
form fractures that provide passageways for the circulation of
fluid.
In a preferred embodiment of the present invention, a borehole is
extended into a relatively low-lying portion of oil shale that
contains or is adjacent to a layer or region that is relatively
rich in water-soluble minerals. Water-soluble minerals, which are
generally saline materials, are frequently encountered in oil
shales in the United States, such as the Green River formation in
Colorado, in the form of beds, lenses, nodules, nodes, veins or the
like. Such minerals include the alkali metal halide salts such as
the sodium or potassium chlorides and/or water soluble
heat-sensitive carbonate minerals such as nahcolite, trona, or the
like.
Portions of subterranean oil shale that contain selected mineral
components such as heat-sensitive carbonate minerals and/or water
soluble minerals, can be located by means of known geological
investigation procedures and equipment. Such procedures are
preferably utilized to locate a portion of an oil shale that
contains heat-sensitive carbonate mineral and is adjacent to a
portion or layer of water-soluble mineral. The water-soluble
mineral is utilized to form a cavern or cavity in contact, for
example, along its roof, with the oil shale. The cavern formation
can readily be accomplished by means of known techniques, such as
solution mining and/or mechanical mining, hydraulic and/or
explosive fracturing, slurry mining, or the like, that are
currently available
Wells 3 and 4 are drilled and completed in horizontally-spaced
locations within the oil shale. The wells are preferably spaced
close enough to facilitate their interconnection by forming and
propagating fractures through or along the boundaries of the
nahcolite layer 2. The nahcolite layer, or at least the upper
portion of it, can be solution-mined by circulating an aqueous
fluid, which can advantageously be warmed and/or made acidic,
between the wells. The mining and/or extensive fracturing forms a
cavern or cavity 6 extending to a fluid-communicative contact with
the wells 3 and 4 and the oil shale 1. The wells may be initially
completed by installing and cementing casing and perforating them
only along the sections adjacent to the cavity. As known to those
skilled in the art, by reversing the flow direction of the solution
mining fluid, varying the injection and production pressures, and
the like, the cavity 6 can be provided with a signficant areal
extent.
After the cavity 6 has been formed, the injection well 3 and the
production wells 4 preferably opened along substantially all of the
oil shale interval, for example, by perforating a well casing. As
known to those skilled in the art, in certain situation, "barefoot"
or open hole completions can be utilized. The injection well 3 is
preferably equipped with fluid inflow conduit arrangement, such as
tubing string 8 and packer 9, to facilitate an inflow of a hot
fluid, such as steam, from a surface location into contact with the
oil shale 1. An injection well 3, when opened into a vertical
interval of the oil shale, particularly when the oil shale is
contacted with a hot fluid, is apt to become partly or completely
filled with oil shale chunks or rubble 10.
The oil-shale-contacting hot fluid used in this invention can
comprise aqueous or nonaqueous fluids such as superheated, dry, or
wet, steam or substantially any gas, vapor or liquid, such as
carbon dioxide, phenols, hydrocarbons, alcohols, halogenated
hydrocarbons, acids, or the like, or substantially any hot aqueous
liquid solution, such as an aqueous acid or base or solution of
neutral salt. The inflowing hot fluid can be heated by means of
surface located and/or downhole located heaters, such as steam
generators, water heaters or the like. The heating can be effected
or supplemented by an in situ combustion within the oil shale
formation. The inflowing fluid is preferably (at least at some
location within the cavity) a hot aqueous fluid having a
temperature of from about 250.degree.F to a temperature sufficient
to cause a relatively rapid oil shale pyrolysis (e.g., from about
600.degree.-1,000.degree.F), with sufficient aqueous liquid being
present (or being formed by steam condensation) to dissolve a
significant portion of inorganic solid material.
The production wells 4 are each equipped with an arrangement for
returning the circulating fluid to a surface location, such as
tubing 11 and packer 12. The fluid-return, or production conduit,
is preferably arranged to provide an inlet above, but in fluid
communication with, the cavity 6.
Where a single pattern of wells is opened into a cavity, the well
pattern can advantageously be one such as a five spot (Or six, or
seven, or nine spot) with the injection well in the center and the
producing wells relatively uniformly displaced radially around the
injection well. Where a cavity is extended into and around a
plurality of patterns of wells, the patterns are preferably
arranged so that the fluid injected through each injection well is
produced through a plurality of producing wells, i.e., so that the
cavity interconnects the wells of a well pattern in which the ratio
of production wells to injections wells is greater than 1 (and thus
the well patterns are preferably a series serious of seven spot or
nine spot patterns).
The flow directions and velocities of fluids within the wells and
the cavity are illustrated by the arrows in the drawing. In the
injection well 3 the velocity of the inflowing fluid is relatively
high. However, as fluid moves radially through cavity 6 the flow
velocity diminishes and, by the time it reaches any of the
production wells, the velocity is relatively low. In accordance
with this invention, the rates and velocities are controlled so
that in an intermediate zone between the injection and production
wells the flow velocity diminishes to one at which significantly
sized particles of mineral solids are dropped out of the flowing
fluids to form a layer such as layer 7 along the bottom of the
cavity. The so-deposited solids are repetitively swept by incoming
portions of the hot fluid and subsequently become substantially
completely depleted of shale oil. Plugging is avoided since the
flow within the cavity is substantially radially outward from the
injection well with each increment of flowing fluid moving towards
larger and larger volumes of free space within the cavity. Any
localized plugs thus tend to be temporarily by passed and
subsequently depleted as their exposed surfaces are swept by the
incoming portions of hot fluid.
As indicated by the dashed line 13 around the borehole of the
injection well 3, with the time, the extraction of organic and
inorganic components from the borehole walls causes the walls to
move generally radially outward. As known to those skilled in the
art periodic expansions of a cavity and/or revisions of the
patterns of flow within the wells in a cavity can be employed to
vary or enhance the rate or extend of oil recovery as long as the
well patterns are arranged to include at least one injection well
and the fluid injected through it is produced from a plurality of
surrounding production wells.
The rates and/or amount of carbonate and/or other heat sensitive or
water soluble minerals removed by the hot fluid can be controlled,
for example by alternating slugs of aqueous and nonaqueous fluids
to vary the rates of extraction of water soluble minerals.
* * * * *