Surface gas correction by group contribution equilibrium model

• US 10,641,757 B2
• Filed: 03/26/2014
• Issued: 05/05/2020
• Est. Priority Date: 03/27/2013
• Status: Active Grant

• Current Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Original Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Inventors: Rowe, Mathew Dennis
• Primary Examiner(s): Betsch, Regis J
• Assistant Examiner(s): Knox, Kaleria
• Application Number:
  US14/769,653
• Publication Number:
  US 20160003793A1
• Time in Patent Office: 2,232 Days
• CPC Class Codes: E21B 49/005 Testing the nature of borehole walls or the formation by using drilling mud or cutting data
• CPC Class Codes: E21B 49/08 Obtaining fluid samples or testing fluids, in boreholes or wells
• CPC Class Codes: G01N 33/241 for hydrocarbon content
• CPC Class Codes: G01N 33/2823 Raw oil, drilling fluid or polyphasic mixtures

Abstract

Methods and systems are disclosed to determine total hydrocarbons from fluid-carrying fluids and solids from a geological formation during downhole operations. Gas extraction at a well site occurs through a gas extractor at a set pressure, detected temperature, detected density, and controlled volume rate. The quantities of various components of interest are determined from samples of fluid influent and effluent from the wellbore by solving a system of equations of state using a group contribution equilibrium model. Knowing approximate chemical compositions of the liquid fluid and solid phases before contamination with formation materials, with the detection of the gas phase and description of the solid phase from the geological formation, allows for determination of total detectable hydrocarbons from geological formations at the surface, and their concentrations to be expressed as mole or mass fraction for materials coming from a wellbore while downhole operations.

Claims

1. A method for characterizing formation fluid, comprising:

extracting a gas sample from a fluid exposed to a formation during downhole operations;

predetermining a chemical composition of a virgin fluid prior to exposing the virgin fluid to the formation;

exposing the virgin fluid to the formation;

measuring a temperature of the gas sample;

determining from the gas sample a vapor-phase molar contribution of each of one or more components of interest in the fluid exposed to the formation;

determining a partial vapor pressure for each component of interest using the temperature;

determining a liquid-phase molar contribution of each component of interest using the determined partial vapor pressure and the determined vapor-phase molar contribution and a vapor-liquid group contribution equilibrium equation of state; and

subtracting the predetermined chemical composition of the virgin fluid from a sum of the determined vapor-phase and liquid-phase molar contributions of all the components of the fluid exposed to the formation to characterize the formation fluid.

2. The method of claim 1, wherein extracting the gas sample comprises extracting an effluent or influent gas sample.

3. The method of claim 1, wherein calculating the liquid-phase molar contribution of each component further comprises:

for each of the one or more components, equating a liquid-phase fugacity to a vapor-phase fugacity, in which the vapor-phase fugacity is a mathematical product of the vapor-phase molar contribution, a vapor-phase fugacity coefficient of the component in the fluid, and the pressure, and in which the liquid-phase fugacity is a mathematical product of at least the liquid-phase molar contribution, a liquid-phase fugacity coefficient of the component as a pure substance at saturation, and an activity coefficient of the component; and

for all of the one or more components collectively, simultaneously solving a system of group contribution equations of state for the liquid-phase molar contribution(s) and the activity coefficient(s).

4. The method of claim 3, wherein the activity coefficient(s) are based on equations from one of the group comprising a Universal Quasi-Chemical Activity Coefficient Model, a Universal Quasi-Chemical Functional-Group Activity Coefficient Model, a modified Universal Quasi-Chemical Functional-Group Activity Coefficient Model, and a Dortmund modified Universal Quasi-Chemical Functional-Group Activity Coefficient Model.

5. The method of claim 1, wherein determining the partial vapor pressure for each the component further comprises calculating the partial vapor pressure for each the component using an Antoine vapor pressure equation.

6. The method of claim 1, further comprising:

extracting an influent gas sample at a influent temperature and a influent pressure from a fluid influent entering a borehole in the formation during downhole operations;

measuring the influent gas sample to determine an influent vapor-phase molar contribution of each of the components in the fluid influent;

determining an influent partial vapor pressure for each the component using the influent temperature; and

determining an influent liquid-phase molar contribution of each component using the influent partial vapor pressure and the influent vapor-phase molar contribution and the vapor-liquid group contribution equilibrium equation of state,

whereby the influent vapor-phase and influent liquid-phase molar contributions of all the components and a known chemical composition of virgin fluid collectively define a composition of influent fluid, thereby compensating for recycled formation gas in the fluid influent.

7. The method of claim 1, further comprising:

extracting a volume of the gas sample using a carrier gas;

using at least one of the group comprising a gas chromatographer or a mass spectrometer to measure the vapor-phase molar contribution of each the component;

removing a carrier gas contribution from the vapor-phase molar concentration(s); and

normalizing the formation fluid by a volume of formation drilled per lineal depth.

8. A system for characterizing formation fluid, comprising:

a virgin fluid that circulates in a downhole fluid circulation system;

a gas extractor fluidly coupled to a flow of fluid within a downhole fluid circulation system;

a temperature detector coupled to the extractor;

a pressure detector coupled to the extractor;

gas analyzer that selectively generates an output corresponding to a vapor-phase molar contribution of each of one or more components of interest in the flow of fluid when exposed to a gas sample of the flow of fluid obtained by the gas extractor; and

an information handling system coupled to the temperature detector, the pressure detector, and the gas analyzer, the information handling system comprising a processor and memory device containing a set of instructions that, when executed by the processor, causes the processor to;

determine a partial vapor pressure for each the component using the temperature of the gas sample;

calculate a liquid-phase molar contribution of each the component of interest using the partial vapor pressure and the vapor-phase molar contribution according to a vapor-liquid equilibrium group contribution equation of state; and

subtract a chemical composition of the virgin fluid from a sum of the determined vapor-phase and liquid-phase molar contributions of all the components in the flow of fluid to characterize the formation fluid.

9. The system of claim 8, wherein the gas sample is an effluent or influent gas sample.

10. The system of claim 8, wherein the set of instructions further cause the processor to:

for each of the one or more components, equate a liquid-phase fugacity to a vapor-phase fugacity, in which the vapor-phase fugacity is a mathematical product of the vapor-phase molar contribution, a vapor-phase fugacity coefficient of the component in the fluid, and the pressure, and in which the liquid-phase fugacity is a mathematical product of at least the effluent liquid-phase molar contribution, a liquid-phase fugacity coefficient of the component as a pure substance at saturation, and an activity coefficient of the component; and

for all of the one or more components collectively, simultaneously solve a system of equations of state for the liquid-phase molar contribution(s) and the activity coefficient(s).

11. The system of claim 10, wherein the activity coefficient(s) are based on equations from one of the group comprising a Universal Quasi-Chemical Activity Coefficient Model, a Universal Quasi-Chemical Functional-Group Activity Coefficient Model, a modified Universal Quasi-Chemical Functional-Group Activity Coefficient Model, and a Dortmund modified Universal Quasi-Chemical Functional-Group Activity Coefficient Model.

12. The system of claim 8, wherein the set of instructions further cause the processor to calculate the partial vapor pressure for each the component using an Antoine vapor pressure equation.

13. The system of claim 8, wherein the gas analyzer includes at least one from the group comprising a gas chromatographer and a mass spectrometer.

14. A system for characterizing formation fluid, comprising:

a first extractor fluidly coupled to a fluid circulation system of a borehole in the earth, the first extractor arranged for extracting an effluent gas sample from a fluid effluent exiting the borehole;

a first temperature detector coupled to the first extractor for measuring an effluent temperature of the effluent gas sample;

a first pressure detector coupled to the first extractor for measuring an effluent pressure of the effluent gas sample;

a first gas analyzer coupled to the first extractor and arranged to selectively generate an output corresponding to an effluent vapor-phase molar contribution of each of one or more components of interest in the fluid effluent when exposed to a gas sample of the fluid effluent obtained by the gas extractor;

a second extractor fluidly coupled to the fluid circulation system arranged for extracting an influent gas sample from a fluid influent entering the borehole;

a second temperature detector coupled to the second extractor for measuring an influent temperature of the influent gas sample;

a second pressure detector coupled to the second extractor for measuring an influent pressure of the influent gas sample;

a second gas analyzer coupled to the second extractor and arranged to selectively generate an output corresponding to an influent vapor-phase molar contribution of each of one or more components of interest in the fluid influent when exposed to a gas sample of the drilling fluid influent obtained by the gas extractor; and

an information handling system coupled to the first and second temperature detectors, the first and second pressure detector, and the first and second gas analyzers, the information handling system comprising a processor and memory device containing a set of instructions that, when executed by the processor, causes the processor to;

determine an influent partial vapor pressure for each the component using the influent temperature of the influent gas sample;

determine an influent liquid-phase molar contribution of each the component using the influent partial vapor pressure and the influent vapor-phase molar contribution according to a vapor-liquid equilibrium group contribution equation of state;

determine an effluent partial vapor pressure for each the component using the effluent temperature of the effluent gas sample;

determine an effluent liquid-phase molar contribution of each the component using the effluent partial vapor pressure and the effluent vapor-phase molar contribution according to a vapor-liquid equilibrium group contribution equation of state; and

subtract the determined influent vapor-phase and liquid-phase molar contributions of all the components of the fluid influent from a sum of the determined effluent vapor-phase and liquid-phase molar contributions of all the components of the fluid effluent to characterize the formation fluid.

15. The system of claim 14, wherein the set of instructions further cause the processor to:

for each of the one or more components, equate an effluent liquid-phase fugacity to an effluent vapor-phase fugacity, in which the effluent vapor-phase fugacity is a mathematical product of the effluent vapor-phase molar contribution, a vapor-phase fugacity coefficient of the component in the fluid effluent, and the pressure, and in which the effluent liquid-phase fugacity is a mathematical product of at least the effluent liquid-phase molar contribution, a liquid-phase fugacity coefficient of the component as a pure substance at saturation, and an activity coefficient of the component; and

for all of the one or more components collectively, simultaneously solve a first system of group contribution equations of state for the effluent liquid-phase molar contribution(s) and the activity coefficient(s).

16. The system of claim 15, wherein the set of instructions further cause the processor to:

for each of the one or more components, equate an influent liquid-phase fugacity to an influent vapor-phase fugacity, in which the influent vapor-phase fugacity is a mathematical product of the influent vapor-phase molar contribution, a vapor-phase fugacity coefficient of the component in the fluid influent, and the pressure, and in which the influent liquid-phase fugacity is a mathematical product of the influent liquid-phase molar contribution, the liquid-phase fugacity coefficient of the component as a pure substance at saturation, and the activity coefficient of the component; and

for all of the one or more components collectively, simultaneously solve a second system of group contribution equations of state for the influent liquid-phase molar contribution(s) and the activity coefficient(s).

17. The system of claim 16, wherein the activity coefficient(s) are based on equations from one of the group consisting of a Universal Quasi-Chemical Activity Coefficient Model, a Universal Quasi-Chemical Functional-Group Activity Coefficient Model, a modified Universal Quasi-Chemical Functional-Group Activity Coefficient Model, and a Dortmund modified Universal Quasi-Chemical Functional-Group Activity Coefficient Model.

18. The system of claim 14, wherein the set of instructions further cause the processor to:

calculate the effluent partial vapor pressure for each the component using an Antoine vapor pressure equation; and

calculate the influent partial vapor pressure for each the component using the Antoine vapor pressure equation.

19. A method for characterizing formation fluid, comprising:

predetermining a chemical composition of a virgin fluid;

extracting an effluent gas sample from fluid of a borehole;

determining an effluent liquid-phase molar contribution of each component of the effluent gas sample using a vapor-liquid group contribution equilibrium equation of state; and

characterizing formation fluid based upon the effluent liquid-phase molar contribution of each component of the effluent gas sample by subtracting the chemical composition of the virgin fluid from a sum of the determined effluent vapor-phase and liquid-phase molar contributions of all the components of the fluid of the borehole.

20. The method of claim 19, further comprising:

extracting an influent gas sample from the fluid of the borehole;

determining an influent liquid-phase molar contribution of each component of the influent gas sample using a second vapor-liquid group contribution equilibrium equation of state; and

compensating for recycled formation gas in the fluid through analysis of the influent liquid-phase molar contributions of all the components and a known chemical composition of virgin fluid.