Prediction of asphaltene onset pressure gradients downhole
A method for predicting asphaltene onset pressure in a reservoir is provided. In one embodiment, the method includes performing downhole fluid analysis of formation fluid via a downhole tool at a measurement station at a first depth in a wellbore and determining an asphaltene gradient for the formation fluid at the measurement station. Asphaltene onset pressure for a second depth in the wellbore may then be predicted based on the downhole fluid analysis and the determined asphaltene gradient. Additional methods, systems, and devices are also disclosed.
1. A method comprising:
performing downhole fluid analysis of formation fluid via a downhole tool at a measurement station at a first depth in a wellbore;
determining an asphaltene gradient for the formation fluid at the measurement station; and
predicting asphaltene onset pressure for a second depth in the wellbore based on results of the downhole fluid analysis and the determined asphaltene gradient, wherein asphaltene onset pressure corresponds to a pressure at which asphaltene precipitation begins.
2. The method of claim 1 , comprising evaluating reservoir connectivity based on the predicted asphaltene onset pressure for the second depth.
3. The method of claim 2 , wherein evaluating reservoir connectivity includes comparing the predicted asphaltene onset pressure for the second depth with a measured asphaltene onset pressure that is measured at the second depth.
4. The method of claim 3 , wherein evaluating reservoir connectivity includes determining whether the magnitude of the difference between the measured asphaltene onset pressure at the second depth and the predicted asphaltene onset pressure for the second depth is below a threshold.
5. The method of claim 4 , comprising affirming reservoir connectivity based on a determination that the magnitude of the difference between the measured asphaltene onset pressure at the second depth and the predicted asphaltene onset pressure for the second depth is below the threshold.
6. The method of claim 4 , comprising identifying reservoir compartmentalization based on a determination that the magnitude of the difference between the measured asphaltene onset pressure at the second depth and the predicted asphaltene onset pressure for the second depth is above the threshold.
7. The method of claim 6 , comprising identifying, based on the identification of reservoir compartmentalization, an additional station in the wellbore at which to perform downhole fluid analysis of formation fluid via the downhole tool and determine an asphaltene gradient for the formation fluid.
8. The method of claim 7 , comprising:
performing downhole fluid analysis of formation fluid via the downhole tool at the additional station; and
determining the asphaltene gradient for the formation fluid at the additional station.
9. The method of claim 1 , comprising using the Flory-Huggins-Zuo equation of state model in determining the asphaltene gradient for the formation fluid at the measurement station.
10. The method of claim 9 , comprising using a cubic equation of state with the Flory-Huggins-Zuo equation of state model in determining the asphaltene gradient for the formation fluid at the measurement station.
11. The method of claim 1 , comprising identifying a flow assurance problem based on the predicted asphaltene onset pressure for the second depth and an asphaltene onset pressure measured at the second depth.
12. A method comprising:
obtaining characteristics of samples of live oil drawn from a formation at multiple depths within a wellbore through downhole fluid analysis;
determining asphaltene gradients for the samples; and
predicting asphaltene instability for additional depths within the wellbore based on the obtained characteristics and the determined asphaltene gradients, wherein predicting asphaltene instability comprises predicting asphaltene onset pressures for the additional depths, and asphaltene onset pressure corresponds to a pressure at which asphaltene precipitation begins.
13. The method of claim 12 , wherein predicting asphaltene instability includes performing phase equilibrium calculations at the multiple depths.
14. The method of claim 13 , comprising verifying that the live oil is stable in a single-phase state without asphaltene separation before performing the phase equilibrium calculations.
15. The method of claim 12 , wherein predicting asphaltene instability includes analyzing asphaltene instability using the Flory-Huggins regular solution model.
16. The method of claim 12 , comprising determining the sizes of asphaltenes of the samples and checking the determined sizes for consistency with the Yen-Mullins model.
17. An apparatus comprising:
a downhole sampling tool including a downhole fluid analysis module configured to determine parameters of sampled fluids; and
a controller operable to predict asphaltene onset pressure at a depth in a well based on parameters determined by downhole fluid analysis for a fluid sampled from a formation by the downhole sampling tool at another depth in the well, wherein asphaltene onset pressure corresponds to a pressure at which asphaltene precipitation begins.
18. The apparatus of claim 17 , wherein the controller is operable to compare a predicted asphaltene onset pressure at the depth in the well to a measured asphaltene onset pressure at the depth and to characterize a reservoir based on the comparison.
19. The apparatus of claim 17 , wherein the controller is operable to predict asphaltene onset pressure at the depth in the well based on parameters determined by downhole fluid analysis for the fluid sampled from the formation by the downhole sampling tool at another depth in the well and from an asphaltene gradient determined at the another depth.
20. The apparatus of claim 17 , wherein at least a portion of the controller is provided within the downhole sampling tool.