Identifying field development opportunities for increasing recovery efficiency of petroleum reservoirs

• US 9,710,766 B2
• Filed: 10/26/2011
• Issued: 07/18/2017
• Est. Priority Date: 10/26/2011
• Status: Active Grant

• Current Assignee: QRI Group, LLC
• Original Assignee: QRI Group, LLC
• Inventors: Saleri, Nansen G., Toronyi, Robert M., Broussard, Joey D.
• Primary Examiner(s): Nghiem, Michael
• Application Number:
  US13/282,282
• Publication Number:
  US 20130110571A1
• Time in Patent Office: 2,092 Days
• Field of Search: 702 6
• CPC Class Codes: G01V 1/50 Analysing data
• CPC Class Codes: G06Q 10/04 Forecasting or optimisation specially adapted for administrative or management purposes, e.g. linear programming or "cutting stock problem" market predictions or forecasting for commercial activities G06Q30/0202

Abstract

Performing a Recovery Design Assessment™ (RDA™) for a petroleum producing field provides a novel indicator and metric that is designed to assess how to improve recovery efficiency of a petroleum producing field. A combination of global benchmark analysis and reservoir management assessment is utilized to identify areas of reservoir management that can be improved to increase recovery efficiency. Global benchmark analysis can include comparing a recovery efficiency for a petroleum reservoir to that of other benchmark petroleum reservoirs to indicate if alterations to recovery design or developments plans or reservoir management optimizations are to be pursued. Management of the petroleum reservoir is assessed to identify recovery obstacles potentially reducing recovery efficiency. Development opportunities for overcoming recover obstacles can be implemented to increase recovery efficiency.

Claims

1. A method of performing a recovery design assessment for a petroleum producing field in order to identify one or more key recovery obstacles impeding the petroleum producing field from achieving an estimated maximum recovery efficiency and adjusting operation of one or more production units to remove or mitigate the one or more key recovery obstacles and thereby increase a recovery efficiency of the petroleum producing field, the method comprising:

measuring, using one or more sensors placed in a petroleum reservoir supplying the petroleum producing field, physical or geological characteristics of the petroleum reservoir directly or indirectly relating to at least some of reservoir pressure, fluid saturation, well productivity and drawdown, fluid profile, oil production, gas production, water production, injection rate, displacement efficiency, sweep efficiency, bypassed petroleum, gas breakthrough, water breakthrough, depletion rate, compartmentalization, vertical and/or horizontal discontinuity, reservoir thickness, reservoir permeability, permeability, fluid viscosity, reservoir depth, and sand problems;

generating a reservoir management rating for the petroleum reservoir supplying the petroleum producing field based at least in part from data measured by the one or more sensors placed in the petroleum reservoir supplying the petroleum producing field;

generating the estimated maximum recovery efficiency for the petroleum producing field based on an estimated ultimate recovery factor and a geo-technical index incorporating at least some of the one or more physical or geological characteristics of the petroleum reservoir measured by the one or more sensors;

identifying, at least in part from data obtained by the one or more sensors placed in the petroleum reservoir supplying the petroleum producing field and by relating the reservoir management rating to the petroleum producing field'"'"'s estimated maximum recovery efficiency, the one or more key recovery obstacles that impede the petroleum producing field from achieving the estimated maximum recovery efficiency; and

adjusting operation of the one or more production units to remove or mitigate the one or more key recovery obstacles and thereby increase the recovery efficiency, wherein the one or more production units are selected from producing oil wells, water injection wells, gas injection wells, heat injectors, or one or more sub-components of the one or more production units, and wherein adjusting the operation of the one or more production units is selected from change in volume, change in pressure, change in temperature, change in well bore path, drilling one or more new production units, implementing peripheral water flooding, re-activating an existing well, or shutting down one or more existing production units.

2. The method as recited in claim 1, wherein generating the reservoir management rating comprises obtaining data relating to one or more of:

reservoir management design, reserves appreciation, development and operating plan, reservoir surveillance and monitoring, technology application, and knowledge management.

3. The method as recited in claim 1, wherein generating the reservoir management rating comprises obtaining a plurality of different portions of data and assigning a weight to each of portion of data in the plurality of different portions of data.

4. The method as recited in claim 1, wherein the geo-technical index is calculated based on a compartmentalization factor, a transmissibility index, and a depth factor determined for the petroleum producing field.

5. The method as recited in claim 4, wherein the compartmentalization factor accounts for compartmentalization or discontinuities within a reservoir.

6. The method as recited in claim 4, wherein the geo-technical index (GTI) for the petroleum producing field is calculated as follows:

GTI=n_a*A+n_b*B+n_c*C

where;

A=the compartmentalization factor,

B=the transmissibility index,

C=the depth factor, and

n_a, n_b, and n_c=weighting coefficients.

7. The method as recited in claim 4, wherein the petroleum producing field'"'"'s estimated maximum recovery efficiency is indicative of a selected recovery efficiency for petroleum producers using designated practices and technology to extract petroleum from petroleum reservoirs having the calculated geo-technical index.

8. The method as recited in claim 1, wherein identifying the one or more key recovery obstacles that impede the petroleum producing field from achieving the estimated maximum recovery efficiency comprises identifying one or more of:

a decline of reservoir pressure, a specified loss in sweep efficiency, bypassed petroleum, gas breakthrough, water breakthrough, and a specified depletion rate.

9. The method as recited in claim 1, wherein identifying the one or more key recovery obstacles that impede the petroleum producing field from achieving the estimated maximum recovery efficiency comprises identifying one or more primary factors and one or more secondary factors, the primary factors requiring additional alterations to recovery design or development plan, the secondary factors being addressable through reservoir management optimizations.

10. The method as recited in claim 1, wherein adjusting the operation of the one or more production units comprises one or more manual or automatic adjustments to one or more infrastructure elements of the petroleum producing field or one or more recovery processes, wherein the one or more manual or automatic adjustments extend the amount of time the petroleum producing field can operate at a specified oil production rate.

11. The method as recited in claim 1, wherein adjusting the operation of the one or more production units comprises one or more manual or automatic adjustments to one or more infrastructure elements of the petroleum producing field or one or more recovery processes, wherein the one or more manual or automatic adjustments increase a cumulative output of the petroleum producing field by at least a specified amount over time.

12. In a computing system having a processor and system memory, a method of performing a recovery design assessment for a petroleum producing field in order to identify one or more key recovery obstacles impeding the petroleum producing field from achieving an estimated maximum recovery efficiency and adjusting operation of one or more production units to remove the one or more key recovery obstacles and thereby increase a recovery efficiency of the petroleum producing field, the method comprising:

inputting into the computing system data relating to one or more physical or geological characteristics of a petroleum reservoir supplying the petroleum producing field, the one or more physical or geological characteristics determined at least in part by one or more sensors placed in the petroleum reservoir supplying the petroleum producing field, the one or more physical or geological characteristics of the petroleum reservoir directly or indirectly relating to at least some of reservoir pressure, fluid saturation, well productivity and drawdown, fluid profile, oil production, gas production, water production, injection rate, displacement efficiency, sweep efficiency, bypassed petroleum, gas breakthrough, water breakthrough, depletion rate, compartmentalization, vertical and/or horizontal discontinuity, reservoir thickness, reservoir permeability, fluid viscosity, reservoir depth, and sand problems;

the computing system generating a reservoir management rating for the petroleum reservoir supplying the petroleum producing field based at least in part on the one or more physical or geological characteristics of the petroleum producing field;

the computing system generating the estimated maximum recovery efficiency for the petroleum producing field based at least in part on an estimated ultimate recovery factor and a geo-technical index incorporating at least some of the one or more physical or geological characteristics of the petroleum reservoir measured by the one or more sensors;

the computing system identifying, at least in part from data relating to the one or more physical or geological characteristics of the petroleum producing field, and by relating the reservoir management rating to the petroleum producing field'"'"'s estimated maximum recovery efficiency, the one or more key recovery obstacles that impede the petroleum producing field from achieving the estimated maximum recovery efficiency;

the computing system determining the one or more field development opportunities to address the one or more key recovery obstacles and thereby increase the recovery efficiency of the petroleum producing field; and

adjusting operation of the one or more production units to remove the one or more key recovery obstacles and thereby increase the recovery efficiency, wherein the one or more production units are selected from producing oil wells, water injection wells, gas injection wells, heat injectors, or one or more sub-components of the one or more production units, and wherein adjusting the operation of the one or more production units is selected from change in volume, change in pressure, change in temperature, change in well bore path, drilling one or more new production units, implementing peripheral water flooding, re-activating an existing well, or shutting down one or more existing production units.

13. The method of claim 12, wherein generating the reservoir management rating comprises obtaining data relating to a plurality of categories of reservoir management effectiveness, including obtaining data related to corresponding subcategories within each of the plurality of categories of reservoir management effectiveness.

14. The method of claim 13, wherein generating the reservoir management rating comprises generating a score for each of the plurality of categories of reservoir management effectiveness based on the corresponding subcategories.

15. The method of claim 12, wherein generating the reservoir management rating comprises accessing data relating to a plurality of categories of reservoir management effectiveness comprises accessing data related to one or more of:

reservoir management design, reserves appreciation, development plan, operating plan, reservoir surveillance, reservoir monitor, technology application, and knowledge management.

16. A method of performing a recovery design assessment for a petroleum producing field in order to identify one or more key recovery obstacles impeding the petroleum producing field from achieving an estimated maximum recovery efficiency and adjusting operation of one or more production units to remove the one or more key recovery obstacles and thereby increase a recovery efficiency of the petroleum producing field, the method comprising:

measuring, using one or more sensors placed in a petroleum reservoir supplying the petroleum producing field, physical or geological characteristics of the petroleum reservoir directly or indirectly relating to at least some of reservoir pressure, fluid saturation, well productivity and drawdown, fluid profile, oil production, gas production, water production, injection rate, displacement efficiency, sweep efficiency, bypassed petroleum, gas breakthrough, water breakthrough, depletion rate, compartmentalization, vertical and/or horizontal discontinuity, reservoir thickness, reservoir permeability, fluid viscosity, reservoir depth, and sand problems;

generating a reservoir management rating for the petroleum reservoir supplying the petroleum producing field based at least in part from data measured by the one or more sensors placed in the petroleum reservoir supplying the petroleum producing field;

calculating a geotechnical index (GTI) for the petroleum reservoir, wherein calculating the geo-technical index (GTI) comprises;

generating a compartmentalization factor data relating to compartmentalization of or discontinuities within the petroleum reservoir, the compartmentalization of or discontinuities within the petroleum reservoir being measured by the one or more sensors placed in the petroleum reservoir;

generating a transmissibility index relating to transmissibility of petroleum through the petroleum reservoir, wherein the transmissibility of petroleum through the petroleum reservoir is based at least in part from transmissibility data measured by the one or more sensors placed in the petroleum reservoir;

generating a depth factor relating to one or more depths of the petroleum reservoir, the one or more depths being measured by the one or more sensors placed in the petroleum reservoir; and

relating the compartmentalization factor, the transmissibility index, and the depth factor to one another;

determining an estimated ultimate recovery factor percentage, wherein the estimated ultimate recovery factor percentage is representative of the estimated maximum recovery efficiency at one or more other petroleum reservoirs having geology similar to the petroleum reservoir;

generating the estimated maximum recovery efficiency for the petroleum reservoir by relating the estimated ultimate recovery percentage to the geo-technical index for the petroleum reservoir;

based at least in part on the reservoir management rating and the estimated maximum recovery for the petroleum reservoir, identifying the one or more key recovery obstacles that impede the petroleum producing field from achieving the estimated maximum recovery efficiency; and

adjusting operation of the one or more production units to remove the one or more key recovery obstacles and thereby increase the recovery efficiency, wherein the one or more production units are selected from producing oil wells, water injection wells, gas injection wells, heat injectors, or one or more sub-components of the one or more production units, and wherein adjusting the operation of the one or more production units is selected from change in volume, change in pressure, change in temperature, change in well bore path, drilling one or more new production units, implementing peripheral water flooding, re-activating an existing well, or shutting down one or more existing production units.

17. The method of claim 16, further comprising determining one or more of gaps and deficiencies in the client'"'"'s asset management design and further plans;

and identifying opportunities to address the one or more of the gaps and deficiencies.

18. The method of claim 16, wherein the estimated ultimate recovery factor percentage is a benchmark recovery efficiency for oil fields that use reservoir management best practices and technology.

19. The method of claim 16, wherein the geo-technical index (GTI) is calculated as follows:

GTI=n_A·

A+n_B·

B+n_c·

C

where,

A is a compartmentalization factor that accounts for compartmentalization or discontinuities, including vertical and/or horizontal discontinuities, within a reservoir,

B is a transmissibility Index that accounts for reservoir thickness (net-to-gross), permeability, and fluid viscosity,

C is a depth factor that accounts for the depth of the reservoir, and

n_A, n_B, and n_C are weight coefficients.

20. In a computing system having a processor and system memory, a method of performing a recovery design assessment for a petroleum producing field in order to identify one or more key recovery obstacles impeding the petroleum producing field from achieving an estimated maximum recovery efficiency and adjusting operation of one or more production units to remove the one or more key recovery obstacles and thereby increase a recovery efficiency of the petroleum producing field, the method comprising:

inputting into the computing system data relating to one or more physical or geological characteristics of a petroleum reservoir supplying the petroleum producing field, the one or more physical or geological characteristics of the petroleum reservoir determined at least in part by one or more sensors placed in the petroleum reservoir supplying the petroleum producing field, the one or more physical or geological characteristics of the petroleum reservoir directly or indirectly relating to at least some of reservoir pressure, fluid saturation, well productivity and drawdown, fluid profile, oil production, gas production, water production, injection rate, displacement efficiency, sweep efficiency, bypassed petroleum, gas breakthrough, water breakthrough, depletion rate, compartmentalization, vertical and/or horizontal discontinuity, reservoir thickness, reservoir permeability, fluid viscosity, reservoir depth, and sand problems;

the computing system generating a reservoir management rating for the petroleum reservoir supplying the petroleum producing field based at least in part on the one or more physical or geological characteristics of the petroleum producing field;

the computing system calculating a geo-technical index (GTI) for the petroleum reservoir, wherein calculating the geo-technical index (GTI) comprises;

receiving or generating a compartmentalization factor relating to compartmentalization of or discontinuities within the petroleum reservoir;

receiving or generating a transmissibility index relating to transmissibility of petroleum through the petroleum reservoir;

receiving or generating a depth factor relating to a depth of the petroleum reservoir; and

relating the compartmentalization factor, the transmissibility index, and the depth factor to one another;

the computing system determining an estimated ultimate recovery factor percentage, wherein the estimated ultimate recovery factor percentage is representative of the estimated maximum recovery efficiency at one or more other petroleum reservoirs having geology similar to the petroleum reservoir;

the computing system generating the estimated maximum recovery efficiency for the petroleum reservoir by relating the estimated ultimate recovery percentage to the geo-technical index for the petroleum reservoir;

based at least in part on the reservoir management rating and the estimated maximum recovery for the petroleum reservoir, identifying the one or more key recovery obstacles that impede the petroleum producing field from achieving the estimated maximum recovery efficiency; and

adjusting operation of the one or more production units to remove the one or more key recovery obstacles and thereby increase the recovery efficiency, wherein the one or more production units are selected from producing oil wells, water injection wells, gas injection wells, heat injectors, or one or more sub-components of the one or more production units, and wherein adjusting the operation of the one or more production units is selected from change in volume, change in pressure, change in temperature, change in well bore path, drilling one or more new production units, implementing peripheral water flooding, re-activating an existing well, or shutting down one or more existing production units.

21. The method of claim 20, wherein the geo-technical index (GTI) is calculated as follows:

GTI=n_A·

A+n_B·

B+n_C·

C

where,

A is a compartmentalization factor that accounts for compartmentalization or discontinuities, including vertical and/or horizontal discontinuities, within a reservoir,

B is a transmissibility Index that accounts for reservoir thickness (net-to-gross), permeability, and fluid viscosity,

C is a depth factor that accounts for the depth of the reservoir, and

n_A, n_B, and n_C are weight coefficients.