Smart pressure driven automated fluid injection management system and method
A method for allocating optimum fluid volume among a set of injectors of a hydrocarbon reservoir includes, for each of multiple depletion stages of the reservoir, determining reservoir pressure at a first region, corresponding to a first injector, in relation to average field reservoir pressure, determining reservoir pressure at a second region, corresponding to a second injector, in relation to average field reservoir pressure, and injecting fluid through the first and second injectors independently and as a function of the determined reservoir pressures at the first and second regions respectively.
1 . A method for allocating optimum fluid volume among a set of injectors of a hydrocarbon reservoir, the method comprising:
for each of multiple depletion stages of the hydrocarbon reservoir:
determining reservoir pressure at a first region, corresponding to a first injector, in relation to average field reservoir pressure,
determining reservoir pressure at a second region, corresponding to a second injector, in relation to the average field reservoir pressure, and
injecting fluid through the first injector and the second injector independently and as a function of the reservoir pressure at the first region and the reservoir pressure at the second region respectively.
2 . The method of claim 1 , wherein the injecting is further a function of quality and heterogeneity of reservoir formation.
3 . The method of claim 1 , wherein the injecting is further a function of location and potential of the first injector and the second injector.
4 . The method of claim 1 , wherein the injecting is further a function of regional reservoir depletion status.
5 . The method of claim 1 , wherein the injecting is performed in accordance with a factor f governed by equation:
f
=
A
×
e
B
×
(
Pres
Pswp
)
C
where
f: is the factor proportional to allocated gas or water injection,
A: is a first pressure balance coefficient,
B: is a second pressure balance coefficient,
C: is a third pressure balance coefficient,
Pres: is the average field reservoir pressure, and
Pswp: is a static injector well pressure.
6 . The method of claim 1 , wherein the fluid is water.
7 . The method of claim 1 , wherein the fluid is brine.
8 . The method of claim 1 , wherein the fluid is gas.
9 . The method of claim 1 , wherein the fluid is carbon dioxide.
10 . The method of claim 1 , wherein the fluid is nitrogen.
11 . A hydrocarbon reservoir pressure management system comprising:
a plurality of injectors, each injector associated with at least one region of a field of a hydrocarbon reservoir;
a pressure injection controller configured to receive as inputs physical data and measurement data in connection with the hydrocarbon reservoir; and
a balancer operable to, at successive reservoir depletion stages:
determine from the physical data and the measurement data, reservoir pressures at first and second regions in relation to average field reservoir pressure, and
independently drive injection volumes of first and second injectors, respectively corresponding to the first and second regions, based on the reservoir pressures.
12 . The hydrocarbon reservoir pressure management system of claim 11 , wherein the physical data and the measurement data includes quality and heterogeneity of reservoir formation.
13 . The hydrocarbon reservoir pressure management system of claim 11 , wherein the physical data and the measurement data includes location and potential of the first and second injectors.
14 . The hydrocarbon reservoir pressure management system of claim 11 , wherein the physical data and the measurement data includes regional reservoir depletion status.
15 . The hydrocarbon reservoir pressure management system of claim 11 , wherein the balancer drives the injection volumes of the first and second injectors in accordance with a factor f governed by equation:
f
=
A
×
e
B
×
(
Pres
Pswp
)
C
where
f: is the factor proportional to allocated gas or water injection,
A: is a first pressure balance coefficient,
B: is a second pressure balance coefficient,
C: is a third pressure balance coefficient,
Pres: is the average field reservoir pressure, and
Pswp: is a static injector well pressure.
16 . A non-transitory machine-readable storage medium having stored thereon a computer program for allocating optimum fluid volume among a set of injectors of a hydrocarbon reservoir, the computer program comprising a routine of set instructions for causing a machine to perform steps of:
for each of multiple depletion stages of the hydrocarbon reservoir:
determining reservoir pressure at a first region, corresponding to a first injector, in relation to average field reservoir pressure,
determining reservoir pressure at a second region, corresponding to a second injector, in relation to the average field reservoir pressure, and
injecting fluid through the first injector and the second injector independently and as a function of the reservoir pressure at the first region and the second region respectively.
17 . The non-transitory machine-readable storage medium of claim 16 , wherein the injecting is further a function of quality and heterogeneity of reservoir formation.
18 . The non-transitory machine-readable storage medium of claim 16 , wherein the injecting is further a function of location and potential of the first injector and the second injector.
19 . The non-transitory machine-readable storage medium of claim 16 , wherein the injecting is further a function of regional reservoir depletion status.
20 . The non-transitory machine-readable storage medium of claim 16 , wherein the injecting is performed in accordance with a factor f governed by equation:
f
=
A
×
e
B
×
(
Pres
Pswp
)
C
where
f: is the factor proportional to allocated gas or water injection,
A: is a first pressure balance coefficient,
B: is a second pressure balance coefficient,
C: is a third pressure balance coefficient,
Pres: is the average field reservoir pressure, and
Pswp: is a static injector well pressure.