Optimizing oil recovery and reducing water production in smart wells

Patent metadata

Field	Value
Publication number	US-9745833-B2
Application number	US-201514768838-A
Country	US
Kind code	B2
Filing date	Mar 31, 2015
Priority date	Apr 1, 2014
Publication date	Aug 29, 2017
Grant date	Aug 29, 2017

Abstract

A method and non-transitory program carrier device tangibly carrying computer executable instructions for adjusting downhole valve settings in order to optimize oil recovery and reduce water production from a well. The method and non-transitory program carrier device are particularly advantageous in wells with intelligent completions that are often referred to as smart wells. In the oil and gas industry, an Internal Control Valve (ICV) is an important tool for both reactive and proactive approaches to adjust ICV settings to improve oil recovery.

First claim

The invention claimed is:

1. A method for optimizing oil recovery and reducing water production in a well, which comprises:
a) calculating surface values for respective parameters of the well using static data for the well and at least one of dynamic data for the well and adjusted dynamic data for the well; said respective parameters of the well comprising at least one selected from the group consisting of well productivity index, water and oil flow rates, flowing bottom hole pressure, water cut and gas-to-oil ratio; wherein the static data for the well comprises at least one selected from the group consisting of well trajectory, well log profiles, relative permeability curves, pressure, volume, temperature, completion, well connection in horizontal section, permeability, initial saturation along well connection in horizontal section, valve coefficient, valve position and skin factor; and wherein said dynamic data comprises at least one selected from the group consisting of average oil, water and gas saturations and bottom hole pressure for each well connection and average static pressure for the well;
b) performing history matching to compare the calculated surface values with real-time surface values for the respective parameters and to produce a misfit representing a surface model;
c) adjusting one or more values in the dynamic data, which represents the adjusted dynamic data, and repeating steps a)-c) until the misfit representing the surface model is ≦10% with respect to the real-time surface values;
d) calculating an optimal downhole valve setting for each completion zone in the well using a 3D grid simulation model and at least one of the surface model and a downhole model;
e) updating the 3D grid simulation model using the adjusted dynamic data and a current downhole valve setting for each completion zone in the well;
f) calculating a cumulative oil value over a predetermined forecasted time period at a predetermined forecasted time interval using the updated 3D grid simulation model and the current downhole valve setting for each completion zone in the well;
g) calculating a maximum cumulative oil value over the predetermined forecasted time period at the predetermined forecasted time interval using the updated 3D grid simulation model and a new optimal downhole valve setting for each completion zone in the well that is based on a simulation to maximize the cumulative oil value; and
h) using one of the optimal downhole valve setting for each completion zone in the well and the new optimal downhole valve setting for each completion zone in the well, adjusting the current downhole valve setting for each completion zone in the well to optimize oil recovery and reduce water production in the well.

2. The method of claim 1 , wherein the misfit represents a difference between the calculated surface values and the real-time surface values.

3. The method of claim 1 , further comprising:
i) calculating downhole values for respective parameters of the well using the static data and one of the dynamic data and the adjusted dynamic data;
j) performing history matching to compare the calculated downhole values with downhole values for the respective parameters from production logging test data and to produce a misfit representing the downhole model; and
k) adjusting the one or more values in the dynamic data, which represents the adjusted dynamic data, and repeating steps a)-k) until the misfit representing the downhole model is ≦10% of the calculated downhole value.

4. The method of claim 3 , wherein the downhole values for the respective parameters of the well comprise values for a gas-to-oil ratio, water cut, and influx water and oil rates for each well connection.

5. The method of claim 3 , wherein the misfit represents a difference between the calculated downhole values and the downhole values from the production logging test data.

6. The method of claim 1 , wherein the adjusted dynamic data comprises values for water and gas saturations.

7. The method of claim 1 , wherein the static data is data collected for a predetermined period of time.

8. The method of claim 1 , wherein the dynamic data is real-time data collected for a predetermined interval of time that is averaged over the predetermined interval of time.

9. A non-transitory program carrier device tangibly carrying computer-executable instructions for optimizing oil recovery and reducing water production in a well, the instructions being executable to implement:
a) calculating surface values for respective parameters of the well using static data for the well and one of dynamic data for the well and adjusted dynamic data for the well; said respective parameters of the well comprising at least one selected from the group consisting of well productivity index, water and oil flow rates, flowing bottom hole pressure, water cut and gas-to-oil ratio; wherein the static data for the well comprises at least one selected from the group consisting of well trajectory, well log profiles, relative permeability curves, pressure, volume, temperature, completion, well connection in horizontal section, permeability, initial saturation along well connection in horizontal section, valve coefficient, valve position and skin factor; and wherein said dynamic data comprises at least one selected from the group consisting of average oil, water and gas saturations and bottom hole pressure for each well connection and average static pressure for the well;
b) performing history matching to compare the calculated surface values with real-time surface values for the respective parameters and to produce a misfit representing a surface model;
c) adjusting one or more values in the dynamic data, which represents the adjusted dynamic data, and repeating steps a)-c) until the misfit representing the surface model is ≦10% with respect to the real-time surface values;
d) calculating an optimal downhole valve setting for each completion zone in the well using a 3D simulation model and at least one of the surface model and a downhole model;
e) updating the 3D grid simulation model using the adjusted dynamic data and a current downhole valve setting for each completion zone in the well;
f) calculating a cumulative oil value over a predetermined forecasted time period at a predetermined forecasted time interval using the updated 3D grid simulation model and the current downhole valve setting for each completion zone in the well;
g) calculating a maximum cumulative oil value over the predetermined forecasted time period at the predetermined forecasted time interval using the updated 3D grid simulation model and a new optimal downhole valve setting for each completion zone in the well that is based on a simulation to maximize the cumulative oil value; and
h) using one of the optimal downhole valve setting for each completion zone in the well and the new optimal downhole valve setting for each completion zone in the well, adjusting the current downhole valve setting for each completion zone in the well to optimize oil recovery and reduce water production in the well.

10. The program carrier device of claim 9 , wherein the misfit represents a difference between the calculated surface values and the real-time surface values.

11. The program carrier device of claim 9 , further comprising:
i) Calculating downhole values for respective parameters of the well using the static data and one of the dynamic data and the adjusted dynamic data;
j) performing history matching to compare the calculated downhole values with downhole values for the respective parameters from production logging test data and to produce a misfit representing the downhole model; and
k) adjusting the one

Assignees

• Landmark Graphics Corp

Inventors

• Carvajal Gustavo
• Boisvert Ian
• Knabe Steven

Classifications

• E21B43/14

  Obtaining from a multiple-zone well · CPC title

• E21B33/12

  Packers; Plugs (used for cementing E21B33/134, E21B33/16) · CPC title

• E21B43/12

  Methods or apparatus for controlling the flow of the obtained fluid to or in wells (E21B43/25 takes precedence; valve arrangements E21B34/00) · CPC title

• E21B43/00 Primary

  Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells (applicable only to water E03B) · CPC title

• G06F30/20

  Design optimisation, verification or simulation (optimisation, verification or simulation of circuit designs G06F30/30) · CPC title