Method and system for performing formation fluid test, involves performing second test with second set of tool parameters and comparing

1. A method for performing a formation fluid test:

inserting a formation testing tool into a wellbore to a first location within the wellbore, wherein the formation testing tool comprises:

at least one probe;

at least one stabilizer;

identifying a first set of tool parameters;

activating the at least one stabilizer into a surface of the wellbore;

activating the at least one probe into a mudcake disposed on the surface of the wellbore;

performing a first test with the formation testing tool to identify a formation fluid property;

inputting the formation fluid property and the first set of tool parameters into a forward model, wherein the forward model performs one or more iterations;

determining a second set of tool parameters from the first set of tool parameters, the formation fluid property, and the forward model;

changing the first set of tool parameters to the second set of tool parameters;

performing a second test with the second set of tool parameters; and

comparing the first test to the second test.

2. The method of claim 1 , wherein the formation fluid property comprises at least one formation fluid property selected from the group consisting of a fluid sample contamination, fluid sample component concentrations, gas-to-oil ratio, water cut, live fluid density, live fluid viscosity, pressure-volume-temperature properties based on a fluid characterization, and combinations thereof.

3. The method of claim 2 , further comprising measuring a sample fluid in the formation testing tool.

4. The method of claim 3 , further comprising storing the sample fluid in a sample chamber if a contamination level is below a contamination level threshold.

5. The method of claim 3 , further comprising removing the sample fluid from the formation testing tool if a contamination level is above a contamination level threshold.

6. The method of claim 1 , further comprising taking pressure test measurements that includes a pressure or a temperature at a location in the wellbore.

7. The method of claim 1 , further comprising extracting a reservoir fluid from a formation with a dual probe section to measure a pressure or a temperature at a location in the wellbore.

8. The method of claim 1 , wherein the forward model first predicts a figure of merit that identifies a relationship between the formation fluid property and the first set of tool parameters.

9. The method of claim 8 , wherein the figure of merit moves towards a maximum to identify the second set of tool parameters.

10. The method of claim 9 , wherein the figure of merit is computed utilizing a gradient based algorithm, Bayesian Optimization, or Simplex Optimization.

11. A system for performing a formation fluid test comprising:

a formation testing tool comprising:

at least one probe, wherein the at least one probe is configured to be disposed in a mudcake along a surface of a wellbore;

at least one stabilizer, wherein the at least one stabilizer is configured to be disposed against the surface of the wellbore;

an information handling machine configured to:

identify a first set of tool parameters;

perform a first test with the formation testing tool to identify a formation fluid property;

input the formation fluid property and the first set of tool parameters into a forward model, wherein the forward model performs one or more iterations;

determine a second set of tool parameters from the first set of tool parameters, the formation parameter, and the forward model;

change the first set of tool parameters to the second set of tool parameters;

perform a second test with the second set of tool parameters; and

compare the first test to the second test.

12. The system of claim 11 , wherein the formation fluid property comprises at least one formation fluid property selected from the group consisting of a fluid sample contamination, fluid sample component concentrations, gas-to-oil ratio, water cut, live fluid density, live fluid viscosity, pressure-volume-temperature properties based on a fluid characterization, and combinations thereof.

13. The system of claim 12 , wherein the formation testing tool is further configured to measure a sample fluid in the formation testing tool.

14. The system of claim 13 , wherein the formation testing tool is further configured to store a sample fluid in the sample chamber if a contamination level is below a contamination level threshold.

15. The system of claim 13 , wherein the formation testing tool is further configured to remove the sample fluid from the formation testing tool if a contamination level is above a contamination level threshold.

16. The system of claim 11 , wherein the formation testing tool is further configured to take pressure test measurements that includes a pressure or a temperature at a location in the wellbore.

17. The system of claim 11 , wherein the formation testing tool is further configured to extract a reservoir fluid from a formation with a dual probe section to measure a pressure or a temperature at a location in the wellbore.

18. The system of claim 11 , wherein the forward model first predicts a figure of merit that identifies a relationship between the formation fluid property and the first set of tool parameters.

19. The system of claim 18 , wherein the figure of merit moves towards a maximum to identify the second set of tool parameters.

20. The system of claim 19 , wherein the figure of merit is computed utilizing a gradient based algorithm, Bayesian Optimization, or Simplex Optimization.