Note: Descriptions are shown in the official language in which they were submitted.
CA 02847770 2014-03-28
PROCESSES FOR TREATING RESERVOIR FLUID COMPRISING MATERIAL
PRODUCED FROM A HYDROCARBON CONTAINING RESERVOIR
FIELD
[0001] The present disclosure relates to recovery and reuse of water from
reservoir fluid
comprising material produced from a hydrocarbon containing reservoir.
BACKGROUND
[0002] Some hydrocarbon production processes, such as Steam-Assisted
Gravity Drainage
("SAGD"), inject steam into a hydrocarbon-containing reservoir to stimulate
production of
hydrocarbons. SAGD uses a pair of wells to produce a hydrocarbon from a
hydrocarbon
containing reservoir. Typically the well pair includes two horizontal wells
vertically spaced
from one another, with the upper well used to inject steam into the reservoir
and the lower well
to produce the hydrocarbon, The steam operates to generate a steam chamber in
the reservoir,
and thermal heat from the steam operates to lower the viscosity of the
hydrocarbon, allowing for
gravity drainage, and thereby production from the production well. The
produced fluids
typically include a mixture of hydrocarbons and water, the water resulting
from the condensing
of the steam (referred to as "produced water").
[0003] For economic and environmental reasons, it is desirable to recycle
the produced
water. Typically, the produced water is treated to remove, amongst other
things, oils and solids,
and then converted into steam using a steam generator.
[0004] The internal energy of produced fluids is not insignificant.
However, such energy is
not being optimally used to drive existing treatment processes.
SUMMARY
[0005] In one aspect, there is provided a process for treating a reservoir
fluid-comprising
mixture, comprising: producing a reservoir fluid-comprising mixture, including
oil and water,
from a hydrocarbon containing reservoir; at a pressure that is greater than
atmospheric pressure,
separating an oil-lean mixture from the reservoir fluid-comprising mixture
such that the
concentration of oil within the oil-lean mixture is greater than 10 ppra; at a
pressure that is
DOOSTOR: 2965059\1
CA 02847770 2014-03-28
greater than atmospheric pressure, effecting separation, from the oil-lean
mixture, of a scale
forming-lean liquid and a scale forming-rich material, by evaporation or
ceramic membrane
filtration; producing pressurized steam from the scale forming-lean liquid
using a steam
generator; and upplying the pressurized steam to the hydrocarbon containing
reservoir for
effecting mobilization of hydrocarbons within the hydrocarbon containing
reservoir.
[00061 In some implementations, the process further comprises, prior to
producing the
pressurized steam, supplying the scale forming-lean liquid to a tank, wherein
the tank is disposed
at a pressure that is greater than atmospheric pressure.
[0007] In some implementations, the concentration of oil within the oil-
lean mixture is
between 10 ppm and 250 ppm.
[00081 In some implementations, the concentration of oil within the oil-
lean mixture is
between 10 ppm and 100 ppm.
[0009] In some implementations, the concentration of oil within the oil-
lean mixture is
between 10 ppm and 30 ppm.
[0010i In some implementations, the pressure is at least 20 kPa above
atmospheric pressure.
[0011] In another aspect, there is provided a process for treating a
reservoir fluid-comprising
mixture, being produced through a wellhead from a hydrocarbon containing
reservoir,
comprising: fluidically coupling the wellhead to a steam generator via a fluid
passage of a fluid
conductor; producing, through a wellhead, a reservoir fluid-comprising
mixture, including oil
and water, from a hydrocarbon containing reservoir; separating an oil-lean
mixture from the
reservoir fluid-comprising mixture such that the concentration of oil within
the oil-lean mixture
is greater than 10 ppm; supplying the oil-lean mixture to a scale-forming
solids separator,
wherein the scale-forming solids separator includes an evaporator or a ceramic
membrane
filtration unit operation; separating, from the oil-lean mixture, a scale
forming-lean liquid and a
scale forming-rich material, using the evaporator; such that each one of (i)
the separating of the
oil-lean mixture from the reservoir fluid-comprising mixture, (ii) the
supplying of the oil-lean
mixture to the evaporator, and (iii) the separating, Man the oil-lean mixture,
of a scale forming-
lean liquid and a scale forming-rich material, using the evaporator is
effected within the fluid
passage, and the entirety of the fluid passage is disposed at a pressure that
is greater than
DOCSTOR; 2985039 VI
CA 02847770 2014-03-28
atmospheric pressure; producing pressurized steam from the scale forming-lean
liquid using the
steam generator; and supplying the pressurized steam to the hydrocarbon
containing reservoir to
effect mobilization of hydrocarbons within the hydrocarbon containing
reservoir.
[0012] In some implementations, the process further comprises, prior to
producing the
pressurized steam, supplying the scale forming-lean liquid to a tank, wherein
the tank is disposed
at a pressure that is greater than atmospheric pressure.
[0013] In some implementations, he concentration of oil within the oil-lean
mixture is
between 10 ppm and 250 ppm.
[0014] In some implementations, the concentration of oil within the oil-
lean mixture is
between 10 ppm and 100 ppm.
[0015] In some implementations, the concentration of oil within the oil-
lean mixture is
between 10 ppm and 30 ppm.
[0016] In some implementations, the pressure is at least 20 kPa above
atmospheric pressure.
[0017] In another aspect, there is provided a process for treating a
reservoir fluid-comprising
mixture, comprising producing a reservoir fluid-comprising mixture, including
oil and water,
from a hydrocarbon containing reservoir; at a pressure that is greater than
atmospheric pressure,
separating an oil-lean mixture from the reservoir fluid-comprising mixture; at
a pressure that is
greater than atmospheric pressure, effecting separation, from the oil-lean
mixture, of a scale
forming-lean liquid and a scale forming-rich material; supplying the scale
forming-lean liquid to
a tank that is disposed at a pressure that is greater than atmospheric
pressure; supplying the scale
forming-lean liquid from the tank to a steam generator; producing pressurized
steam from the
scale fomiing-lean liquid using the steam generator; and supplying the
pressurized steam to the
hydrocarbon containing reservoir to effect mobilization of oil within the
hydrocarbon containing
reservoir.
[0018] In some implementations, the temperature of the scale forming-lean
liquid within the
tank is greater than 100 degrees Celsius.
[0019] In some implementations, the separation, from the oil-lean mixture,
of a scale
forming-lean liquid and a scale forming-rich material, is effected by
evaporation.
DOCSTOR; 29650,1911
1
CA 02847770 2014-03-28
[00201 In some implementations, the separation from the oil-lean mixture,
of a scale
forming-lean liquid and a scale forming-rich material, is effected by
pressurized hot lime
softening,
[0021] In some implementations, the separation, from the oil-lean mixture,
of a. scale
forming-lean liquid and a scale forming-rich material, is effected by ceramic
membrane
filtration.
[0022] In some implementations, the pressure is at least 20 kPa above
atmospheric pressure.
[00231 In another aspect, there is provided a process for treating a
reservoir fluid-comprising
mixture, being produced through a wellhead from a hydrocarbon containing
reservoir,
comprising: fluidically coupling the wellhead to a steam generator via a fluid
passage of a fluid
conductor; producing, through a wellhead, a reservoir fluid-comprising
mixture, including oil
and water, from a hydrocarbon containing reservoir; separating an oil-lean
mixture from the
reservoir fluid-comprising mixture; supplying the oil-lean mixture to a scale
forming solids
separator; separating, from the oil-lean mixture, a scale forming-lean liquid
and a scale forming-
rich material, using the scale forming solids separator; supplying the scale
forming-lean liquid to
a tank that is disposed at a pressure that is greater than atmospheric
pressure; supplying the scale
forming-lean liquid from the tank to a steam generator; such that each one of
(i) the separating of
the oil-lean mixture from the reservoir fluid-comprising mixture, (ii) the
supplying of the oil-lean
mixture to the scale forming solids separator, (iii) the separating, from the
oil-lean mixture, of a
scale forming-lean liquid and a scale forming-rich material, using the scale
forming solids
separator, (iv) the supplying of the scale forming-lean liquid to a tank that
is disposed at a
pressure that is greater than atmospheric pressure, and (v) the supplying of
the scale forming-
lean liquid from the tank to the steam generator is effected within the fluid
passage, and the
entirety of the fluid passage is disposed at a pressure that is greater than
atmospheric pressure;
producing pressurized steam from the scale forming-lean liquid using the steam
generator; and
supplying the pressurized steam to the hydrocarbon containing reservoir to
effect mobilization of
hydrocarbons within the hydrocarbon containing reservoir.
[00241 In some implementations, the temperature of the scale forming-lean
liquid within the
tank is greater than 100 degrees Celsius.
OdenSTOR; 285503911
4
CA 02847770 2014-03-28
[0025] In some implementations, the separation, from the oil-lean mixture,
of a scale
forming-lean liquid and a scale forming-rich material, is effected by
evaporation.
[00261 In some implementations, the separation from the oil-lean mixture,
of a scale
forming-lean liquid and a scale forming-rich material, is effected by
pressurized hot lime
softening,
[0027] In some implementations, the separation, from the oil-lean mixture,
of a scale
forming-lean liquid and a scale forming-rich material, is effected by ceramic
membrane
filtration.
[0028] In some implementations, the pressure is at least 20 Oa above
atmospheric pressure.
[0029] In another aspect, there is provided a process for treating a
reservoir fluid-comprising
mixture, being produced through a wellhead from a hydrocarbon containing
reservoir,
comprising: fluidically coupling the wellhead to a steam generator via a fluid
passage of a fluid
conductor; producing, through a wellhead, a reservoir fluid-comprising
mixture, including oil
and water, from a hydrocarbon containing reservoir; separating an oil-lean
mixture from the
reservoir fluid-comprising mixture; supplying the oil-lean mixture to a scale
forming solids
separator including an evaporator; separating, from the oil-lean mixture, a
scale forming-lean
liquid and a scale forming-rich material, using the scale forming solids
separator; such that each
one of (1) the separating of the oil-lean mixture from the reservoir fluid-
comprising mixture, (ii)
the supplying of the oil-lean mixture to the scale forming solids separator,
and (iii) the
separating, from the oil-lean mixture, of a scale forming-lean liquid and a
scale forming-rich
material, using the scale forming solids separator is effected within the
fluid passage, and the
entirety of the fluid passage is disposed at a pressure that is greater than
atmospheric pressure;
producing pressurized steam from the scale forming-lean liquid using the steam
generator; and
supplying the pressurized steam to the hydrocarbon containing reservoir to
effect mobilization of
hydrocarbons within the hydrocarbon containing reservoir.
[0030] In some implementations, the pressure is at least 20 Icria above
atmospheric pressure.
[0031] In some implementations, the process further comprises progressively
reducing
pressure along a section of the fluid passage, from downstream of the wellhead
to the evaporator.
DOCSTOR: 295503911
CA 02847770 2014-03-28
100321 In another aspect, there is provided a process for treating a
reservoir fluid-comprising
mixture, being produced through a wellhead from a hydrocarbon containing
reservoir,
comprising: fluidically coupling the wellhead to an evaporator via a fluid
passage of a fluid
conductor extending upstream from the evaporator; producing, through a
wellhead, a reservoir
fluid-comprising mixture, including oil and water, from a hydrocarbon
containing reservoir;
separating an oil-lean mixture from the reservoir fluid-comprising mixture;
supplying the oil-
lean mixture to the evaporator; separating, from the oil-lean mixture, an
aqueous liquid distillate
and a scale forming-rich material, using the evaporator; such that each one of
(i) the separating
of the oil-lean mixture from the reservoir fluid-comprising mixture, (ii) the
supplying of the oil-
lean mixture to the evaporator, and (iii) the separating, from the oil-lean
mixture, of an aqueous
liquid distillate and a scale forming-rich material, using the evaporator is
effected within the
fluid passage, and the entirety of a section of the fluid passage, that is
upstream of the
evaporator, is disposed at a temperature of at least (i.e. greater than or
equal to) the boiling point
temperature of the oil-lean mixture at the pressure within the evaporator;
producing pressurized
steam from the aqueous liquid distillate using the steam generator; and
supplying the pressurized
steam to the hydrocarbon containing reservoir to effect mobilization of
hydrocarbons within the
hydrocarbon containing reservoir.
100331 In some implementations, the temperature is at least the boiling
point temperature of
water at 20 kl)a above atmospheric pressure.
100341 In some implementations, the process further comprises, after the
separating, from the
oil-lean mixture, a scale forming-lean liquid and a scale forming-rich
material, using the
evaporator, and prior to the producing pressurized steam from the scale
forming-lean liquid using
the steam generator, cooling the reservoir fluid-comprising mixture with the
scale forming-lean
liquid.
[0035] In some implementations, the effected cooling is such that the oil-
lean mixture has a
temperature of at least the boiling point temperature of the oil-lean mixture
at the pressure within
the evaporator.
[00361 In some implementations, the effected cooling is such that the oil-
lean mixture has a
temperature of at least the boiling point temperature of water at 20 IcPa
above atmospheric
pressure.
DOCSTOR: 290503911
6 _ _
CA 02847770 2016-08-01
[0037] In some implementations, the effected cooling is such that the
temperature of the
cooled reservoir fluid-comprising mixture is such that the specific gravity of
water, within
the cooled reservoir fluid-comprising mixture, is greater than the specific
gravity of oil,
within the cooled reservoir fluid-comprising mixture, by a difference of
between 20 kg/m3
and 70 kg/m3.
[0038] In some implementations, the temperature of the aqueous liquid
distillate is
greater than 100 degrees Celsius.
[0039] In some implementations, the process further comprises,
progressively reducing
temperature along the section of the fluid passage, from downstream of the
wellhead to the
evaporator.
[0040] In some implementations, the hydrocarbon containing reservoir is an
oil sands
reservoir.
10040a1 In another aspect, there is provided a process for recovering
hydrocarbons from a
hydrocarbon-bearing reservoir, comprising:
injecting steam into the hydrocarbon-bearing reservoir to heat and mobilize
hydrocarbons therein;
at a pressure that is greater than atmospheric pressure, producing a reservoir
fluid-comprising mixture from the hydrocarbon-bearing reservoir at a wellhead,
the reservoir fluid-comprising mixture comprising hydrocarbons and produced
water;
at a pressure that is above atmospheric pressure, separating at least a
portion of
the produced water from the reservoir fluid-comprising mixture; and
at a pressure that is above atmospheric pressure, supplying the at least a
portion
of the produced water to a steam generator for generating the steam.
BRIEF DESCRIPTION OF DRAWINGS
[0041] The preferred embodiments will now be described with the following
accompanying drawings, in which:
7
CA 02847770 2016-08-01
[0042] Figure 1 is a schematic illustration of a well pair in an oil sands
reservoir for
implementation of a steam-assisted gravity drainage process;
[0043] Figure 2 is a process flow diagram illustrating a system for
practising an
embodiment of the process described herein.
DETAILED DESCRIPTION
[0044] Referring to Figures 1 and 2, there is provided a system 100 for
recovering and
reusing water contained within a reservoir fluid-comprising mixture 110 that
is produced
from a hydrocarbon-containing reservoir 30. The recovered water is converted
to high
pressure steam 200 and conducted into the hydrocarbon-containing reservoir for
effecting
production of hydrocarbons from the reservoir. Amongst other things, the
processes
employed within the system are configured to minimize energy losses from the
water being
recovered, and thereby reduce energy requirements for converting the recovered
water into
steam with a steam generator 190. In this respect, in some implementations,
the process is
carried out at a pressure that is greater than atmospheric pressure. In some
implementations,
the pressure is at least 20 kPa above atmospheric pressure.
7a
CA 02847770 2014-03-28
[0045] For illustrative purposes below, an oil sands reservoir from which
bitumen is being
produced using Steam-Assisted Gravity Drainage ("SAGD") is described. However,
it should be
understood, that the techniques described could be used in other types of
hydrocarbon containing
reservoirs and/or with other types of thermal recovery methods that use steam.
[0046] The reservoir fluid-comprising mixture 110 is produced from an oil
sands reservoir
using a SAGD well pair. Referring to Figure 1, in a typical SAGD well pair,
the wells are
spaced vertically from one another, such as wells 10 and 20, and the
vertically higher well, i.e.,
well 10, is used for steam injection the SAGD operation, and the lower well,
i.e., well 20, is used
for producing bitumen. During the SAGD operation, steam injected through the
well 10
(typically referred to as the "injection well") is conducted into the
reservoir 30. The injected
steam mobilizes the bitumen within the oil sands reservoir 30. The mobilized
bitumen and steam
condensate drains through the interwell region 15 by gravity to the well 20
(typically referred to
as the "production well"), collects in the well 20, and is surfaced through
tubing or by artificial
lift to the surface, where it is produced through a wellhead 25.
[0047] The reservoir fluid-comprising mixture 110 includes oil and water.
In some
embodiments, for example, the reservoir fluid-comprising mixture 110 has a
temperature
between 150 degrees Celsius and 250 degrees Celsius. The pressure of the
reservoir fluid-
comprising mixture 110 can range from 1000 ¨ 4000 kPa (gauge), and is
dependent on the
pressure within the reservoir 30.
00481 In some embodiments, for example, the reservoir fluid-comprising
mixture 110 is
conditioned, prior to separation into its material components, to produce a
treated reservoir fluid-
comprising mixture. For example, conditioning of the reservoir fluid-
comprising mixture 110
can includes cooling of the reservoir fluid-comprising mixture 110.
[0049] Downstream separation processes effect separation of an oil-lean
mixture 120 from
the reservoir fluid-comprising mixture 110 (see below), and, in some
embodiments, for example,
such separation processes are temperature dependent. Temperature affects both
density and
viscosity, and both of these parameters affect separation efficiency. To
improve such separation,
the reservoir fluid-comprising mixture 110 may be coaled prior to effecting
the separation. In
cases where the fluid temperature of the reservoir fluid-comprising mixture
110 is relatively low
(such as, for example, 165 degrees Celsius or less), limited or no cooling may
be required.
DOCSTOR: 2965039\1
8
= Pk
CA 02847770 2014-03-28
[0050] In some embodiments, the temperature of the cooled reservoir fluid-
comprising
mixture 110 is such that the specific gravity of water, within the cooled
reservoir fluid-
comprising mixture 110, is greater than the specific gravity of oil, within
the cooled reservoir
fluid-comprising mixture 110, by a difference of between 20 kg/m3 and 70
kg/m3,
[00511 In some embodiments, the conditioning of the reservoir fluid-
comprising mixture
110 includes admixing diluent 220 with the reservoir fluid-comprising mixture.
The admixing of
the diluent 220 enables transport of the recovered oil through a pipeline. The
diluent also affects
the separation of an oil-lean mixture 120 from the cooled reservoir fluid-
comprising mixture 110.
The more diluent that is added, the greater the density difference between the
diluted oil and the
water. Diluent is expensive and there are some losses to the gas phase.
Accordingly, diluent
addition is minimized and limited to what is required such that the diluted
oil meets the sales
pipeline specifications. In some embodiments, the treating may include both
cooling of the
reservoir fluid-comprising mixture and admixing of the reservoir fluid-
comprising mixture with
diluent, in any order.
[0052] In other embodiments, instead of cooling the reservoir fluid-
comprising mixture 110,
the conditioning of the reservoir fluid-comprising mixture 110 includes
heating the reservoir
fluid-comprising mixture 110 such that the density of oil becomes sufficiently
greater than the
density of water so as to enable a desired separation of an oil-lean mixture
120 from the reservoir
fluid-comprising mixture 110. In this case, no diluent is added. In some
implementations, the
separation of an oil-lean mixture 120 from the heated reservoir fluid-
comprising mixture 110 is
effected at about a temperature of 225 degrees Celsius.
[0053] The oil-lean mixture 120 is separated from the reservoir fluid-
comprising mixture 110
(conditioned or unconditioned) within an oil separator 138. In some
embodiments, in separating
the oil-lean mixture 120 from the reservoir fluid-comprising mixture 110, an
oil-rich mixture 130
becomes separated from the oil-lean mixture 120. In some embodiments, the oil
separator 138
includes three stages 140, 150, and 155. Typically, separation in stages 140
and 150 is effected
by gravity separation, while separation in stage 155 functions to provide
final polishing after the
gravity separation to effect production of the oil-lean mixture 120. The total
number of stages
being determined based on a desired separation efficiency, while in keeping
with a desire to
optimize utilization of capital.
DOCSTOR: 286603011
9
CA 02847770 2014-03-28
[0054] In some embodiments, the stage 150 is effected within a vessel
including electrostatic
grids to assist in the separation. In some embodiments, the stage 150 may not
necessarily be
effected within a vessel, but rather a separation device that uses accelerated
gravity forces, such
as a hydrocyclone or a centrifuge, In some embodiments, the stages 140 and 150
may be
combined into a single stage.
[00551 The heavier liquid phase products 142, 152, generated from,
respectively, stages 140,
150, are combined into an intermediate oil-lean mixture 118. The oil-rich
mixture 130 is
conducted to a product holding tank 160. Gaseous material 144, 154, produced
from,
respectively, stages 140, 150, is managed by a vapour handling system.
[00561 The intermediate oil-lean mixture 118 is supplied to a de-oiling
separator 155 for
effecting separation of an oil-rich separation product 124 and the oil-lean
mixture 120. The
separation can be effected by any one, or any combination, of gravity
separation, filters
(coalescing, granular media, cartridge, membrane, screen, pre-coat or types
otherwise capable of
filtering oil droplets), gas flotation units, hydrocyclones, centrifuges, and
devices to improve
coalescing such as plate packs.
100571 The oil-lean mixture 120 is supplied to a scale forming solids
separator 160 for
effecting separation, from the oil-lean mixture 120, of a scale forming-lean
liquid 170 and a scale
forming-rich material 165. The scale forming-rich material can be, for
example, dissolved
solids, suspended solids, or free oil. This separation can be effected, for
example, by
evaporation, pressurized hot lime softening in combination with ion exchange,
or ceramic
membrane filtration in combination with ion exchange. In this respect, in some
embodiments,
the scale forming solids separator 160 may include an evaporator, a
presstuized hot lime
softening unit operation, or a ceramic membrane filtration unit operation.
Scale forming solids
that are concentrated within the scale foiming-rich material, by virtue of the
separation, include
calcium-comprising compounds, magnesium-comprising compounds, and silica. In
some
embodiments, for example, the scale forming-lean liquid 170 is disposed at a
temperature that is
greater than 100 degrees Celsius. Removal of scale-forming materials, prior to
supplying of the
liquid 170 to the steam generator 200, is desirable so as to mitigate scaling
with the steam
generator 200.
DOCSTOR: 296503911
CA 02847770 2014-03-28
[0058] In some embodiments, for example, prior to the supplying of the oil-
lean mixture 120
to the scale forming solids separator 160, the oil-lean mixture 120 is admixed
with chemical
agents 125 for supporting or enabling processes effected within the separator
160, or for
mitigating against undesirable process conditions within the separator 160. In
some
embodiments, for example, where the separator 160 is an evaporator, the
chemical agents 125
can be a pH attenuating agent for mitigating against scale formation. The
chemical agents 125
are typically introduced downstream of the separation of the oil-lean mixture
120 from the
reservoir fluid-comprising mixture 110 so as not to unnecessarily consume the
chemical agents
125 prior to introduction to the separator 160.
[0059] In some embodiments, for example, prior to the supplying of the oil-
lean mixture 120
to the scale forming solids separator 160, the oil-lean mixture 120 is admixed
with make-up
water 122. The make-up water 122 may be added to compensate for reservoir
losses of steam,
and losses within the processing system, such as losses within purge streams.
The make-up
water 122 is typically introduced downstream of the separation of the oil-lean
mixture 120 from
the reservoir fluid-comprising mixture 110 so as not to use up capacity within
the oil separator
138.
[0060] The scale forming-lean liquid 170 is conducted to a steam generator
190 for
conversion to pressurized steam 200 for use in recovering oil from the
hydrocarbon containing
reservoir 30. In this respect, the pressurized steam is conducted to the
hydrocarbon containing
reservoir 30 to effect mobilization of bitumen within the oil sands reservoir
30.
[0061] In one aspect, the separating of an oil-lean mixture 120 from the
reservoir fluid-
comprising mixture 110 is such that the concentration of oil within the oil-
lean mixture is greater
than 10 ppm. In some embodiments, for example, the concentration of oil within
the oil-lean
mixture is between 10 ppm and 250 ppm, In some embodiments, for example, the
concentration
of oil within the oil-lean mixture is between 10 ppm and 100 ppm. In some
embodiments, for
example, the concentration of oil within the oil-lean mixture is between 10
ppm and 30 ppm.
Separation processes, for effecting the separation, from the oil-lean mixture
120, of the scale
forming-lean liquid 170, in the form of evaporation, or ceramic membrane
filtration in
combination with ion exchange, are, typically, better able to process an oil-
lean mixture 120
having relatively higher oil contents, than other separation processes. As a
result, less costly de-
DOCSTOR; 295503811
11
CA 02847770 2014-03-28
oiling equipment is required to effect the production of the oil-lean mixture
120, having a
relatively higher oil content, when such separation processes are employed.
[00621 In another aspect, prior to being conducted to the steam generator
190, the scale
forming-lean liquid 170 can be supplied to a tank 230. In some embodiments,
for example, the
tank 230 has a volume equivalent to that of providing for a residence time,
for scale forming-lean
liquid 170 being received from the separator 160, of at least about 15
minutes. In some
embodiments, the tank 230 functions as a buffer for receiving surges in
production of the scale
forming-lean liquid 170, and for allowing steam generation to continue during
upsets within
upstream equipment (such as for example, when operation of the separator 160
becomes
suspended) or allowing production of scale forming-lean liquid 170 to continue
during upsets
within downstream equipment (such as, for example, when the steam generator
190 shuts down).
[0063] The wellhead 25 is fluidly coupled the steam generator 190 via a
fluid passage within
a fluid conductor 300 for supplying water contained within the reservoir fluid-
comprising
mixture to the steam generator 190. In some embodiments, the conditioning of
the reservoir
fluid-comprising mixture 110 (if any), the separating of the oil-lean mixture
120 from the
reservoir fluid-comprising mixture 110 (conditioned or unconditioned), the
supplying of the oil-
lean mixture 120 to the separator 160, and the separating of the scale forming-
lean liquid 170
from the oil-lean mixture 120 is effected within the fluid passage. In other
embodiments, for
example, the fluid passage extends from the heat exchanger 210 to the steam
generator 190, such
that the separating of the oil-lean mixture 120 from the reservoir fluid-
comprising mixture 110,
the supplying of the oil-lean mixture 120 to the separator 160, the separating
of the scale
forming-lean liquid 170 from the oil-lean mixture 120, the cooling of the
reservoir fluid-
comprising mixture 110 by the scale forming-lean liquid 170, and the supplying
of the scale
forming-lean liquid 170 to the steam generator 190 is effected within the
fluid passage.
[00641 In another aspect, the entirety of the fluid passage of the fluid
conductor 300 is
disposed at a pressure that is greater than atmospheric pressure. In some
implementations,
additional compression machinery, downstream of the wellhead 25, for
pressurizing the
conducted fluid (in these instances, for example, such pressurization is
effected by subsurface
pumps), is not provided (in other embodiments, compression machinery may be
provided
immediately downstream of the wellhead 25 for assisting with production from
the well) yet the
DOCSTOR: 296503011
12
CA 02847770 2014-03-28
oil-lean mixture 120 is supplied to the separator 160 at a pressure that is
greater than atmospheric
pressure. In this respect, the pressure within the fluid passage of the fluid
conductor 300
becomes progressively less up to at least the separator 160, but is still
maintained above the
pressure within the separator 160. In some implementations, each one of: (i)
the conditioning
(such as heating or cooling) of the reservoir fluid-comprising mixture, (ii)
the separating of an
oil-lean mixture from the cooled reservoir fluid-comprising mixture, (iii) the
supplying of the oil-
lean mixture to the separator 160, (iv) the separating of the scale forming-
lean liquid 170 from
the oil-lean mixture 120, (v) the cooling of the reservoir fluid-comprising
mixture 110 by the
scale forming-lean liquid 170, and (vi) the supplying of the scale forming-
lean liquid 170 to the
steam generator 190 is effected at a pressure that is greater than atmospheric
pressure. In some
of these implementations, for example, this pressure is at least 20 Oa above
atmospheric
pressure. In some of these implementations, for example, pressure along a
section of fluid
passage, from downstream of the wellhead to the evaporator, is progressively
reduced.
[0065] By avoiding having to, e.g., as an intermediate step between the
wellhead and the
separator 160, reduce fluid pressure within the fluid passage, such as, to
atmospheric pressure,
and then elevate the fluid pressure to above atmospheric pressure (e.g., when
an intermediate
unit operation is provided and operated at atmospheric pressure, such as an
atmospheric storage
tank), it may be possible to avoid capital cost associated with additional
compression machinery
that may be required to effect the supply of the scale-forming lean liquid 170
to the steam
generator 190 at a sufficiently high pressure. Such compression machinery may
include
compression machinery disposed upstream of the separator 160 for supplying the
oil-lean
mixture to the separator 160 at a pressure that is greater than atmospheric
pressure.
[0066] When the separator 160 includes an evaporator, by supplying the oil-
lean mixture 120
to the evaporator at a pressure that is greater than atmospheric pressure, the
evaporator may be
operated more efficiently or may occupy a smaller footprint.
[0067] When the separator 160 includes an evaporator, the evaporator
effects evaporation of
a portion of the oil-lean mixture to produce the scale forming-lean liquid 170
in the form of an
aqueous liquid distillate. The residue remaining after the evaporation of a
portion of the oil-lean
mixture includes dissolved solids. Periodically, this residue is purged from
the evaporator 160 as
the scale forming-rich material 165 for disposal.
DOCSTOR: 2065039\1
13
CA 02847770 2014-03-28
10068] In some embodiments, the reservoir fluid-comprising mixture 110 is
indirectly cooled
by the scale forming-lean liquid 170. In this respect, the scale forming-lean
liquid is supplied to
the heat exchanger 210. Such supplying effects indirect heat transfer
communication between
the supplied scale forming-lean liquid 170 and the reservoir fluid-comprising
mixture 110 within
the heat exchanger 210. As a result, heat is transferred, within the heat
exchanger 210, from the
hotter reservoir fluid-comprising mixture 110 to the cooler scale forming-lean
liquid 170,
thereby effecting cooling of the reservoir fluid-comprising mixture 110,
without requiring an
external heat sink.
[0069J In another aspect, where the separator 160 includes an evaporator,
an upstream fluid
passage portion of the fluid conductor 300 is provided, and the upstream fluid
passage portion
extends upstream from the evaporator 160, and the entirety of the upstream
fluid passage portion
is disposed at a temperature that is at least (i.e .greater than or equal to)
the boiling point
temperature of the oil-lean mixture 120 at the pressure within the evaporator
160. In some
implementations, for example, this temperature is at least the boiling point
temperature of water
at 20 IrPa above atmospheric pressure. In some implementations, each one of:
(i) the
conditioning (such as heating or cooling) of the reservoir fluid-comprising
mixture, (ii) the
separating of an oil-lean mixture from the cooled reservoir fluid-comprising
mixture, and (iii) the
supplying of the oil-lean mixture to the separator 160 is effected at a
temperature that is at least
(i.e. greater than or equal to) the boiling point temperature of the oil-lean
mixture 120 at the
pressure within the evaporator 160, such as at least the boiling point
temperature of water at 20
kPa above atmospheric pressure. In some implementations, the temperature along
the section of
fluid passage 300, from downstream of the wellhead to the evaporator, is
progressively reduced
to the boiling point temperature of the oil-lean mixture 120 at the pressure
within the evaporator
160.
[00701 By avoiding having to, e.g., as an intermediate step between the
wellhead and the
separator 160, reduce temperature within the fluid passage below that of the
boiling point
temperature of the oil-lean mixture 120 at the pressure within the evaporator
160, and then to
elevate the temperature to, or above, the boiling point temperature of the oil-
lean mixture 120 at
the pressure within the evaporator, it may be possible to avoid costs
associated with additional
heating of the scale-forming lean liquid 170 prior to supply to, or within,
the evaporator.
DOCSTOR: 296503911
14
CA 02847770 2014-03-28
[0071) In a related aspect, the scale forming-lean liquid 170 is the
aqueous liquid distillate,
such that the aqueous liquid distillate 170 is supplied to the heat exchanger
210 to function as the
cooling fluid. The reservoir fluid-comprising mixture 110 is cooled by the
aqueous liquid
distillate 170 to a temperature that is sufficient to enable the desired
separation of the oil-lean
mixture 120 from the reservoir fluid-comprising mixture 110 within the oil
separator 138 but is
maintained at a temperature that is greater than, or equal to, the boiling
point temperature of the
mixture 120 at the pressure within the evaporator 160 (for example, greater
than, or
equal to, the boiling point temperature of water at 20 kPa above atmospheric
pressure). In some
implementations, the cooling of the reservoir fluid-comprising mixture 110 is
to a temperature
that is sufficiently high such that, even with heat losses, after the
separation of the oil-lean
mixture from the cooled reservoir fluid-comprising mixture 110, the
temperature of the oil-lean
mixture 120 being supplied to the evaporator 160 is greater than, or equal to,
the boiling point
temperature of the oil-lean mixture at the pressure within the evaporator 160.
In some
implementations, the temperature of the oil-lean mixture, supplied to the
evaporator 160, is
greater than, or equal to, the boiling point temperature of water at 20 kPa
above atmospheric
pressure. Again, this may potentially eliminate the requirement for either a
heat exchange step
between the hotter distillate 170 and the incoming feed of the oil-lean
mixture 120 to the
evaporator 160, or the input of additional heat within the evaporator
processes.
[00721 In those embodiments where cooling of the reservoir fluid-comprising
mixture 110 is
being effected by the aqueous liquid distillate 170, in some of these
embodiments, the cooling is
such that a desired separation of the oil-lean mixture 120 from the reservoir
fluid-comprising
mixture 110 is facilitated, while still enabling the supply of the oil-lean
mixture 120 to the
evaporator at a temperature that is greater than, or equal to, the boiling
point temperature of the
oil-lean mixture at the pressure within the evaporator 160. In other
embodiments, there is
additional quenching effect provided by added diluent, make-up water, and
other cooler process
streams, and such additional quenching effect complements the heat exchange
between the
aqueous liquid distillate 170 and the reservoir fluid-comprising mixture 110
such that an
additional external heat sink is not required for facilitating a desired
separation of the oil-lean
mixture 120 from the reservoir fluid-comprising mixture 110 while still
enabling the supply of
the oil-lean mixture 120 to the evaporator at a temperature that is greater
than, or equal to, the
boiling point temperature of the oil-lean mixture at the pressure within the
evaporator 160, In
DOCSTOR: 296503911
CA 02847770 2014-03-28
some cases, an additional external heat sink may be provided if such
operational flexibility is
desired and additional cooling, prior to supplying of the oil-lean mixture 120
to the evaporator
160, is required. Alternatively, the operating temperature of the evaporator
160 could be reduced
(such as by reducing the pressure of the oil-lean mixture 120 being supplied
to the evaporator) so
as to avoid incorporation of an additional external heat sink.
[0073) Reference throughout the specification to "one
embodiment/implementation," "an
embodiment/implementation," "some embodiments/implementations," "one aspect,"
"an aspect,"
or "some aspects" means that a particular feature, structure, method, or
characteristic described
in connection with the embodiment/implementation or aspect is included in at
least one
embodiment/implementation of the present invention. In this respect, the
appearance of the
phrases "in one embodiment/implementation" or "in an
embodiment/implementation" or "in
some embodiments/implementations" in various places throughout the
specification are not
necessarily all referring to the same embodiment/implementation. Furthermore,
the particular
features, structures, methods, or characteristics may be combined in any
suitable manner in one
or more embodiments/implementations.
[0074] Each numerical value should be read once as modified by the term
"about" (unless
already expressly so modified), and then read again as not so modified unless
otherwise
indicated in context. Also, in the summary and this detailed description, it
should be understood
that a concentration range listed or described as being useful, suitable, or
the like, is intended that
any and every concentration within the range, including the end points, is to
be considered as
having been stated. For example, "a range of from 1 to 10" is to be read as
indicating each and
every possible number along the continuum between about 1 and about 10. Thus,
even if specific
data points within the range, or even no data points within the range, are
explicitly identified or
refer to only a few specific data points, it is to be understood that
inventors appreciate and
understand that any and all data points within the range are to be considered
to have been
specified, and that inventors have disclosed and enabled the entire range and
all points within the
range.
[0075] In the above description, for purposes of explanation, numerous
details are set forth in
order to provide a thorough understanding of the present disclosure. However,
it will be
apparent to one skilled in the art that these specific details are not
required in order to practice
DOCSTOR: 2985039\1
16
CA 02847770 2016-08-01
the present disclosure. Although certain dimensions and materials are
described for
implementing the disclosed example embodiments, other suitable dimensions
and/or
materials may be used within the scope of this disclosure. All such
modifications and
variations, including all suitable current and future changes in technology,
are believed to be
within the sphere and scope of the present disclosure.
17
