A method of performing a stimulation operation for a subterranean formation penetrated by a wellbore is provided. The method involves collecting pressure measurements of an isolated interval of the wellbore during injection of an injection fluid therein, generating a fracture closure from the pressure measurements, generating transmissibility based on the fracture closure and a mini fall off test of the isolated interval during the injection, obtaining fracture geometry from images of the subterranean formation about the isolated interval, and generating system permeability from the transmissibility and the fracture geometry. The method may also involve deploying a wireline stimulation tool into the wellbore, isolating an interval of the wellbore and injecting fluid into the interval with the wireline stimulation tool. The fracture geometry may be obtained by imaging the formation, and fracture geometry may be obtained from core sampling.

The invention relates to a method, a system and a computer program product for ascertaining a plant property of a useful plant in a field, wherein external data concerning the useful plant are stored in a memory unit, wherein a measurement device ascertains a raw measured value relating to at least one plant property, and wherein a calibrated or corrected value for the plant property is ascertained on the basis of the raw measured value taking account of the external data from the memory unit.

The invention relates to a method, a system and a computer program product for ascertaining a plant property of a useful plant in a field, wherein external data concerning the useful plant are stored in a memory unit, wherein a measurement device ascertains a raw measured value relating to at least one plant property, and wherein a calibrated or corrected value for the plant property is ascertained on the basis of the raw measured value taking account of the external data from the memory unit.

The impact of a stabilizing additive for treating oil-based fluids having destabilized solids, such as asphaltenes and polynuclear aromatics, may be quantitatively assessed, by determining the settling rate of flocculated destabilized solids in samples of untreated oil-based fluids and oil-based fluids treated with the stabilizing additive through the use of a turbidity meter or nephelometer while the field and quantifying the difference between the two settling rates to determine if a change in the amount of stabilizing additive applied to the oil-based fluid is necessary.

The impact of a stabilizing additive for treating oil-based fluids having destabilized solids, such as asphaltenes and polynuclear aromatics, may be quantitatively assessed, by determining the settling rate of flocculated destabilized solids in samples of untreated oil-based fluids and oil-based fluids treated with the stabilizing additive through the use of a turbidity meter or nephelometer while the field and quantifying the difference between the two settling rates to determine if a change in the amount of stabilizing additive applied to the oil-based fluid is necessary.

A method of rock typing includes obtaining mercury injection capillary pressure (MICP) data regarding a region of interest. A distance matrix is computed for distributions determined from the MICP data using a statistical distance metric. A cluster tree of the distributions is generated using the distance matrix. The cluster tree is adjusted based on a petrographic characteristic to produce an adjusted cluster tree, which is used to determine a pore structure types of the region of interest.

A method of rock typing includes obtaining mercury injection capillary pressure (MICP) data regarding a region of interest. A distance matrix is computed for distributions determined from the MICP data using a statistical distance metric. A cluster tree of the distributions is generated using the distance matrix. The cluster tree is adjusted based on a petrographic characteristic to produce an adjusted cluster tree, which is used to determine a pore structure types of the region of interest.

The present disclosure describes methods and systems to enhance subsurface models of fractured reservoirs. In particular, the methods and systems described herein incorporate the effects of “dynamic” compressible fractures and, thus, can improve predictions of fractured reservoir performance over time. The methods and systems may utilize predictive algorithms for mechanical and hydraulic stiffness properties of the fracture network that are based at least in part on a database of measurements derived from single fractures.

Examples of techniques for determining robustness of a discrete fracture network (DFN) permeability estimate are disclosed. In one example implementation according to aspects of the present disclosure, a method may include: receiving a DFN of an earth formation of interest, the DFN comprising a plurality of connected fractures; determining a directional equivalent permeability of the plurality of connected fractures of the DFN using a numerical upscaling method; and determining the robustness of the directional equivalent permeability.

Examples of techniques for determining robustness of a discrete fracture network (DFN) permeability estimate are disclosed. In one example implementation according to aspects of the present disclosure, a method may include: receiving a DFN of an earth formation of interest, the DFN comprising a plurality of connected fractures; determining a directional equivalent permeability of the plurality of connected fractures of the DFN using a numerical upscaling method; and determining the robustness of the directional equivalent permeability.