# US 12,180,422 B2 · System and method for optimized production of hydrocarbons from shale oil reservoirs via cyclic injection

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- Number: US 12,180,422 B2
- Document ID: US12180422B2
- Status: Granted
- Kind: B2
- Application number: 18/545,652
- Filed: 2023-12-19
- Published: 2024-04-11
- Granted: 2024-12-31
- Earliest claimed: 2019-12-30
- Assignees: Shale Ingenuity, LLC
- Applicants: Shale Ingenuity, LLC
- Inventors: Robert A. Downey
- Web page: https://patentgrep.com/patent/US12180422B2

## CPC

- C09K 8/594: Compositions used in combination with injected gas {, e.g. CO2 orcarbonated gas}(C09K8/592 takes precedence)
- E21B 43/16: Enhanced recovery methods for obtaining hydrocarbons
- E21B 43/166: {Injecting a gaseous medium; Injecting a gaseous medium and a liquid medium (CO2 injection E21B43/164; steam injection E21B43/24)}
- E21B 43/168: {Injecting a gaseous medium}
- E21B 47/06: Measuring temperature or pressure
- E21B 49/087: {Well testing, e.g. testing for reservoir productivity or formation parameters}
- C09K 2208/10: Nanoparticle-containing well treatment fluids
- E21B 2200/20: Computer models or simulations, e.g. for reservoirs under production, drill bits
- C09K: MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- E21B: EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS

## Abstract

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.

## Claims

### Claim 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 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 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 periods, 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.

### Claim 2 (depends on 1)

The method of claim 1, wherein the injection and production process does not comprise a shut-in or soaking step between the injection period and the production period of the plurality of injection and production periods.

### Claim 3 (depends on 1)

The method of claim 1, wherein the injection and production process does comprise a shut-in or soaking step between the injection period and the production period of the plurality of injection and production periods.

### Claim 4 (depends on 1)

The method of claim 1, wherein the step of determining the maximum injection rate and the maximum injection pressure during the injection periods is determined based upon at least one of surface facilities capacities, reservoir and wellbore conditions, and operation constraints.

### Claim 5 (depends on 1)

The method of claim 1, wherein the step of determining the maximum production rate and the minimum production pressure during the production periods is determined based upon at least one of surface facilities capacities, reservoir and wellbore conditions, and operation constraints.

### Claim 6 (depends on 1)

The method of claim 1, wherein the hydrocarbon-containing composition is injected at a temperature of less than 50° F.

### Claim 7 (depends on 1)

The method of claim 1, wherein the increase in the recovery is an increase of at least 75% versus estimated ultimate recovery (EUR).

### Claim 8 (depends on 1)

The method of claim 1, wherein the increase in the recovery is an increase of at least 90% versus estimated ultimate recovery (EUR).

### Claim 9 (depends on 1)

The method of claim 1, wherein the hydrocarbon-containing composition comprises a fluid selected from a group consisting of aliphatic hydrocarbons.

### Claim 10 (depends on 9)

The method of claim 9, wherein the hydrocarbon-containing composition comprises an aliphatic hydrocarbon is selected from the group consisting of ethane, propane, butane, heptane and hexane.

### Claim 11 (depends on 1)

The method of claim 1, wherein an additional injection fluid that is not hydrocarbon is injected during the injection periods.

### Claim 12 (depends on 11)

The method of claim 11, wherein an additional injection fluid comprises water.

### Claim 13 (depends on 12)

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.

### Claim 14 (depends on 11)

The method of claim 11, wherein the additional injection fluid comprises a material selected from the group consisting of liquid surfactants, nano-surfactants, nanoparticles, and combinations thereof.

### Claim 15 (depends on 14)

The method of claim 14, wherein a second additional injection fluid that is a gas at the surface injection conditions is injected during the injection periods.

### Claim 16 (depends on 15)

The method of claim 15, wherein the gas is selected from the group consisting of nitrogen, carbon dioxide, methane, ethane, and carbon monoxide.

### Claim 17 (depends on 11)

The method of claim 11, wherein the additional injection fluid comprises a gas at the surface injection conditions.

### Claim 18 (depends on 17)

The method of claim 17, wherein the gas is selected from the group consisting of nitrogen, carbon dioxide, methane, ethane, and carbon monoxide.