Prediction of reservoir fluid properties from mud-gas data
The present disclosure relates to techniques for prediction of reservoir fluid properties of a hydrocarbon reservoir fluid, such as the density, the saturation pressure, the formation volume factor and the gas-oil ratio of the reservoir fluid. To predict the reservoir fluid properties, a model is generated by selecting a subset of available reservoir samples based on a degree of biodegradation of the samples, generating an input data set comprising input data and target data, the input data comprising measured or predicted mud-gas data; and generating a model using the input data. The application of this technique allows a continuous log of the selected property to be generated using mud-gas data collected during the well drilling process.
1. A method of generating a model for predicting a value of at least one fluid property of a fluid at a first sample location within a hydrocarbon reservoir, comprising:
providing an initial data set relating to a first plurality of second sample locations, the initial data set comprising reservoir fluid properties data for each second sample location;
selecting a second plurality of second sample locations as a subset of the first plurality of second sample locations, the selection being based on a degree of biodegradation of a fluid at the first sample location;
generating an input data set from the initial data set comprising input data and target data, the input data comprising mud-gas data, or a derivative thereof, for the second plurality of second sample locations, and the target data comprising the at least one property of the hydrocarbon reservoir for each of the second plurality of second sample locations; and
generating a model using a correlation between the input data and the target data such that the model can be used to predict the at least one property of the fluid at the first sample location based on measured mud-gas data for the first sample location;
providing measured mud-gas data for the first sample location;
predicting the values of a fluid property of the fluid at the first sample location by supplying the measured mud-gas data to the model;
determining whether the fluid has been biodegraded by comparison of a ratio of i-C4/n-C4 from the measured mud-gas data to a predetermined threshold and/or a ratio of i-C5/n-C5 from the measured mud-gas data to a predetermined threshold; and
providing an indication of confidence associated with the predicted value of the fluid property for the second sample location, wherein the indication of confidence is based on whether the fluid at the first sample location has been biodegraded.
2. A method according to claim 1 , wherein providing the measured mud-gas data comprises:
processing a drilling fluid used whilst drilling through the first sample location to release hydrocarbon gases from the drilling fluid; and
analysing the released hydrocarbon gases to determine their composition, wherein the measured mud-gas data indicates a concentration of the released hydrocarbon gases.