An embodiment in accordance with the present invention includes a method for estimating the permeability of fractured rock formations from the analysis of a slow fluid pressure wave, which is generated by pressurization of a borehole. Wave propagation in the rock is recorded with TFI. Poroelastic theory is used to estimate the permeability from the measured wave speed. The present invention offers the opportunity of measuring the reservoir-scale permeability of fractured rock, because the method relies on imaging a wave, which propagates through a large rock volume, on the order of kilometers in size. Traditional methods yield permeability for much smaller rock volumes: well logging tools only measure permeability in the vicinity of a borehole. Pressure transient testing accesses larger rock volumes; however, these volumes are much smaller than for the proposed method, particularly in low-permeability rock formations.

An embodiment of a method of estimating one or more properties of an earth formation includes acquiring formation fluid data indicative of a qualitative property of a formation fluid in a near-field region of an earth formation surrounding a borehole, the near field region including a surface of the borehole, and acquiring acoustic data based on acoustic signals transmitted into a far-field region of the formation, and estimating a property of one or more fractures in the far-field region based on the acoustic data. The method also includes combining the formation fluid data and the acoustic data, and estimating, by a processing device, at least one fracture characteristic of the formation in the near-field region and the far-field region based on the combined data.

Methods and systems for petrophysical modeling of a subterranean reservoir include generating a first distribution of values representing a fluid volume and a second distribution of values representing a mineral volume of the subterranean formation, the generating being based on a probabilistic mineralogical evaluation; determining a third distribution of values representing a volume of silt distribution in the subterranean formation; and generating a model specifying a predicted permeability distribution for the subterranean formation, the model being based on the first distribution of values representing the fluid volume, the second distribution of values representing the mineral volume, and the third distribution of values representing the volume of silt.

An exemplary embodiment of the invention relates a method for determining hydraulic permeability of rocks in a subsurface region, the method comprising: in-situ measuring and/or calculating at least one of independent seismic velocities of rocks at different locations in said subsurface region; determining at least one lithological unit in said subsurface region based on the measured seismic velocities; for the at least one lithological unit, acquiring at least one rock sample at an at least one location of said subsurface region; measuring the rock-sample porosity and permeability as functions of stress; measuring and/or calculating of at least one of independent seismic velocities of said at least one rock sample as functions of stress; computing the stiff and compliant porosity of said at least one rock sample; computing numerical coefficients of a given analytical permeability model based on the stiff and compliant porosities; computing coefficients of a given analytical model of an elastic-compliance characteristic of the rock based on the stiff and compliant porosity; computing the stiff and compliant porosity for a plurality of other locations in said subsurface region; and computing the permeability of rocks belonging to said at least one lithological unit, for said at least one location in said subsurface region and for said plurality of other locations in said subsurface region.

The disclosed embodiments include a method, apparatus, and computer program product for approximating multiphase flow reservoir production simulation. For example, one disclosed embodiment includes a system that includes at least one processor and memory coupled to the at least one processor, the memory storing instructions that when executed by the at least one processor performs operations that includes generating a set of pseudo-phase production relative permeability curves; receiving production rate history data; receiving simulation configuration parameters; performing flow simulation using the set of pseudo-phase production relative permeability curves; determining an optimal matching pseudo-phase production simulation result that best matches the production rate history data; and performing relative permeability inversion using signal processing analysis of production rate history data to approximate relative permeability curve descriptions with quantified uncertainty.

A method for determining spatial distribution of permeability in a subsurface formation using passive seismic signals includes determining a spatial distribution of a fracture network generated by the pumping of hydraulic fracturing fluid using detected seismic signals resulting from the pumping. A bulk permeability of the fracture network is determined using the detected seismic signals. A formation permeability is determined in each cell of a cellular grid containing the fracture network resulting from the pumping of the hydraulic fracturing fluid. The calculated formation permeability in each cell is then scaled such that the average formation permeability is substantially equal to the bulk permeability to calculate the permeability distribution.

Embodiments of the disclosure provide a method to propagate a set of petrophysical measurements in at least one well to a well not having a full set of petrophysical measurements. The method includes identifying a first data set for a first well. The method also includes identifying a second data set for a second well. Using a mapping derived from the first well, the petrophysical property for measurement A can be derived for the second well from measurement B of the second well.

A device, computer program and related method for processing a first seismic signal that includes identifying one portion of a second seismic signal and determining a length of a seismic wavelet. It is also possible to train a neural network by using a plurality of sub-portions of said portion a input variables and at least one second piece of information as a target variable. Said sub-portions of the portion have a length dependent on the length of the seismic wavelet determined. Finally, the method includes determining at least one first piece of geological information based on the first seismic signal using said trained neural network.

Properties of underground formations are obtained by performing simultaneous geostatistical inversion of two or more seismic datasets acquired over the same area. These methods enable simultaneous estimating quantitative changes in a hydrocarbon-producing field.

A system and method are provided for monitoring a wellbore in a lateral section, during stimulation, with equipment enabling retrieval in many conditions. The method includes monitoring the wellbore with a distributed fiber optic sensor to determine one or more characteristics of the stimulation operation using detected backscattered optical signals on the distributed fiber optic sensor. The method also includes retrieving a cable by exerting a traction force. A downhole device is provided for receiving the cable and includes retainers to maintain the cable and also includes a weakpoint configured to break when subjected to a force along a longitudinal axis of the downhole device that is greater than a predetermined threshold. The system includes the cable having the distributed fiber optic sensor, the downhole device, and a surface monitoring system for determining the characteristic of the stimulation operation using detected backscattered optical signals on the distributed fiber optic sensor.