System and method for optimized production of hydrocarbons from shale oil reservoirs via cyclic injection
System and method for the optimized production of hydrocarbons from shale oil reservoirs via cyclic injection to achieve an improved and optimal recovery of oil. The method can determine and optimize the composition of injected fluids to be injected, the rate, pressure and duration of injection, the production rate and pressure of produced fluids; can determine and utilize the optimum number of injection and production cycles; can determine the amount of soaking time (if any); and can determine the equipment design and operating characteristics to provide for the optimized injection of injection fluids, and the separation of produced fluids for both reinjection and delivery to sales or storage.
1 . A method to increase the recovery of oil from shale reservoirs utilizing a cyclic injection and production process that comprises a plurality of injection and production periods, wherein each of the plurality of injection and production periods comprises an injection period and a production period, and wherein the method comprises the steps of:
(a) determining a hydrocarbon-containing composition for injection to be utilized during a first set of injection and production periods of the plurality of injection and production periods, wherein the hydrocarbon-containing composition comprises a fluid selected from a group consisting of aliphatic hydrocarbons, components of natural gas that are is in a liquid state at surface injection conditions, and combinations thereof;
(b) determining a maximum injection rate and a maximum injection pressure in a well to be utilized during the injection period in each injection and production period of the first set of injection and production periods;
(c) determining a maximum production rate of gases and liquids from the well and a minimum production pressure during the production period in each injection and production period of the first set of injection and production periods;
(d) during the injection period in each injection and production period of the first set of injection and production periods, injecting the hydrocarbon-containing composition for a period of time such that the pressure near a wellbore of the well reaches the determined maximum injection pressure during the injection period;
(e) during the production period in each injection and production period of the first set of injection and production period, producing the well for a period of time to produce fluids, such that the pressure at the wellbore reaches the determined minimum production pressure;
(f) processing the produced fluids at the surface to remove hydrocarbons from the produced fluids;
(g) performing steps (d)-(f) for each of the injection and production periods in the first set of injection and production periods;
(h) at or during end of the first set of injection and production periods, assessing the composition of the produced fluids and recalibrating a reservoir simulation model to determine the composition of the residual oil in the shale reservoir;
(i) adjusting the composition of the hydrocarbon-containing injection fluids to adjusted hydrocarbon-containing injection fluids; and
(j) performing the process of steps (b) through (i) repeatedly for one or more subsequent sets of injection and production periods, wherein the adjusted hydrocarbon-containing injection fluids is utilized as the hydrocarbon-containing injection fluids in each subsequent set of the one or more subsequent sets of injection and production periods.
2 . The method of claim 1 , wherein the hydrocarbon-containing composition comprises a fluid selected from a group consisting of aliphatic hydrocarbons.
3 . The method of claim 2 , wherein the hydrocarbon-containing composition comprises an aliphatic hydrocarbon is selected from the group consisting of ethane, propane, butane, heptane, and hexane.
4 . The method of claim 1 , wherein the hydrocarbon-containing composition comprises a fluid comprising one or more components of natural gas that are in a liquid state at surface injection conditions.
5 . A method to increase the recovery of oil from shale reservoirs utilizing a cyclic injection and production process that comprises a plurality of injection and production periods, wherein each of the plurality of injection and production periods comprises an injection period and a production period, and wherein the method comprises the steps of:
(a) determining a hydrocarbon-containing composition for injection to be utilized during a first set of injection and production periods of the plurality of injection and production periods, wherein the hydrocarbon-containing composition is in a liquid state at surface injection conditions;
(b) determining a maximum injection rate and a maximum injection pressure in a well to be utilized during the injection period in each injection and production period of the first set of injection and production periods;
(c) determining a maximum production rate of gases and liquids from the well and a minimum production pressure during the production period in each injection and production period of the first set of injection and production periods;
(d) during the injection period in each injection and production period of the first set of injection and production periods, injecting the hydrocarbon-containing composition and one or more additional injection fluids for a period of time such that the pressure near a wellbore of the well reaches the determined maximum injection pressure during the injection period;
(e) during the production period in each injection and production period of the first set of injection and production period, producing the well for a period of time to produce fluids, such that the pressure at the wellbore reaches the determined minimum production pressure;
(f) processing the produced fluids at the surface to remove hydrocarbons from the produced fluids;
(g) performing steps (d)-(f) for each of the injection and production periods in the first set of injection and production periods;
(h) at or during end of the first set of injection and production periods, assessing the composition of the produced fluids and recalibrating a reservoir simulation model to determine the composition of the residual oil in the shale reservoir;
(i) adjusting the composition of the hydrocarbon-containing injection fluids to adjusted hydrocarbon-containing injection fluids, wherein the adjusted hydrocarbon-containing composition is in a liquid state at surface injection conditions; and
(j) performing the process of steps (b) through (i) repeatedly for one or more subsequent sets of injection and production periods, wherein the adjusted hydrocarbon-containing injection fluids is utilized as the hydrocarbon-containing injection fluids in each subsequent set of the one or more subsequent sets of injection and production periods.
6 . The method of claim 5 , wherein, during the injection period in each injection and production period of the first set of injection and production periods, the one or more additional injection fluids comprises an additional injection fluid that is injected after injection of the hydrocarbon-containing composition.
7 . The method of claim 6 , wherein the additional injection fluid comprises water.
8 . The method of claim 7 , wherein the additional injection fluid further comprises a material selected from the group consisting of liquid surfactants, nano-surfactants, nanoparticles, and combinations thereof.
9 . The method of claim 6 , wherein the additional injection fluid comprises a gas at the surface injection conditions.
10 . The method of claim 9 , wherein the gas is selected from the group consisting of nitrogen, carbon dioxide, methane, ethane, and carbon monoxide.
11 . The method of claim 9 , wherein during the injection period in each injection and production period of the first set of injection and production periods, the one or more additional injection fluids comprises a second additional injection fluid that is injected after injection of the additional injection fluid.
12 . The method of claim 6 , wherein the second additional injection fluid comprises water.
13 . The method of claim 12 , wherein the additional injection fluid further comprises a material selected from the group consisting of liquid surfactants, nano-surfactants, nanoparticles, and combinations thereof.
14 . The method of claim 13 , wherein the gas is selected from the group consisting of nitrogen, carbon dioxide, methane, ethane, and carbon monoxide.
15 . The method of claim 6 , wherein the additional injection fluid comprises (a) water and (b) a gas at the surface injection conditions.
16 . The method of claim 15 , wherein the additional injection fluid further comprises a material selected from the group consisting of liquid surfactants, nano-surfactants, nanoparticles, and combinations thereof.
17 . The method of claim 16 , wherein the gas is selected from the group consisting of nitrogen, carbon dioxide, methane, ethane, and carbon monoxide.
18 . The method of claim 15 , wherein the gas is selected from the group consisting of nitrogen, carbon dioxide, methane, ethane, and carbon monoxide.
19 . A method to increase the recovery of oil from shale reservoirs utilizing a cyclic injection and production process that comprises a plurality of injection and production periods, wherein each of the plurality of injection and production periods comprises an injection period and a production period, and wherein the method comprises the steps of:
(a) determining a hydrocarbon-containing composition for injection to be utilized during a first set of injection and production periods of the plurality of injection and production periods, wherein the hydrocarbon-containing composition is in a liquid state at surface injection conditions;
(b) determining a maximum injection rate and a maximum injection pressure in a well to be utilized during the injection period in each injection and production period of the first set of injection and production periods;
(c) determining a maximum production rate of gases and liquids from the well and a minimum production pressure during the production period in each injection and production period of the first set of injection and production periods;
(d) during the injection period in each injection and production period of the first set of injection and production periods, thermally injecting the hydrocarbon-containing composition for a period of time such that the pressure near a wellbore of the well reaches the determined maximum injection pressure during the injection period;
(e) during the production period in each injection and production period of the first set of injection and production period, producing the well for a period of time to produce fluids, such that the pressure at the wellbore reaches the determined minimum production pressure;
(f) processing the produced fluids at the surface to remove hydrocarbons from the produced fluids;
(g) performing steps (d)-(f) for each of the injection and production periods in the first set of injection and production periods;
(h) at or during end of the first set of injection and production periods, assessing the composition of the produced fluids and recalibrating a reservoir simulation model to determine the composition of the residual oil in the shale reservoir;
(i) adjusting the composition of the hydrocarbon-containing injection fluids to adjusted hydrocarbon-containing injection fluids, wherein the adjusted hydrocarbon-containing composition is in a liquid state at surface injection conditions; and
(j) performing the process of steps (b) through (i) repeatedly for one or more subsequent sets of injection and production periods, wherein the adjusted hydrocarbon-containing injection fluids is utilized as the hydrocarbon-containing injection fluids in each subsequent set of the one or more subsequent sets of injection and production periods.
20 . The method of claim 19 , wherein the step of thermally injecting the hydrocarbon-containing composition comprises utilizing steam, hot water, a hot solvent, or a combination thereof.