Abstract: Disclosed herein is a method for obtaining depth-variant relative permeability and capillary pressure curves utilizes downhole in-situ logging data and formation testing measurements. The method involves obtaining multi-frequency dielectric data and NMR T2 data under residual water and oil saturation conditions, and obtaining formation testing data from which relative permeability and capillary pressure values are determined. Rock properties related to rock texture and fluid distribution are determined from the obtained multi-frequency dielectric and NMR T2 data. Additional NMR T2 and multi-frequency dielectric data are obtained at various saturation conditions and depths, and data sets are formed based on their possession of similar rock properties. A mathematical function is determined, relating water relative permeability, oil relative permeability, and capillary pressure with water saturation, using the rock properties and formed data sets.

Abstract: Examples described herein provide a computer-implemented method for deriving textural properties of a reservoir formation. The method includes acquiring multi-frequency dielectric data (?meas). The method further includes applying a dielectric mixing model between different fluid phases to generate an effective fluid permittivity (?fluid) by mixing the permittivity of water and hydrocarbon fluids. The method further includes applying the dielectric mixing model between the effective fluid permittivity (?fluid) and a matrix permittivity (?m). The method further includes minimizing a difference between a measured dielectric response and the dielectric mixing model by optimizing model parameters. The method further includes computing a cementation exponent (m) and a saturation exponent (n) from the multi-frequency dielectric data (?meas). The method further includes estimating a formation property based at least in part on the cementation exponent (m) and the saturation exponent (n).

Abstract: A method of estimating a wettability characteristic of a rock and fluid system includes acquiring a sample of the rock material, performing a first nuclear magnetic resonance (NMR) measurement of the sample when the sample is in a full water saturation condition, and measuring a first T2 distribution, performing a second NMR measurement of the sample when the sample is in a second partial saturation condition, and measuring a second T2 distribution. The method also includes separating a hydrocarbon component of the second T2 distribution from a water component of the second T2 distribution, applying a fluid substitution model to the water component of the second T2 distribution to generate a computed T2 distribution, and calculating a wettability index (WI) based on a difference between the first T2 distribution and the computed T2 distribution.

Abstract: A method of estimating a wettability characteristic of a rock material includes acquiring a plurality of T2 distributions based on nuclear magnetic resonance (NMR) measurements of a rock material under a plurality of fluid saturated rock conditions, constructing a measurement matrix based on the plurality of T2 distributions, and performing non-negative factorization of the measurement matrix to determine feature components. The method also includes reconstructing the plurality of T2 distributions based on the feature components, and extracting a first set of T2 distributions associated with mobile water under a wetting condition and a second set of T2 distributions associated with mobile water under a non-wetting condition based on the feature components, and calculating a wettability index (WI) based on the first extracted set of T2 distributions and the second extracted set of T2 distributions.

Abstract: Systems and methods to evaluate a formation by analyzing drill cuttings involve a multi-frequency dielectric coaxial probe to obtain a reflected voltage from a medium under test based on a reference voltage over a frequency range. The medium under test includes the drill cuttings. The system includes a processor to compute an effective permittivity of the drill cuttings over the frequency range based on a reflection coefficient, which is a ratio of the reflected voltage to the reference voltage over the frequency range, and to determine one or more parameters from the effective permittivity. The one or more parameters are used to make decisions about subsequent drilling in the formation.

Abstract: A method of estimating a wettability characteristic of a rock and fluid system includes acquiring a sample of the rock material, performing a first nuclear magnetic resonance (NMR) measurement of the sample when the sample is in a full water saturation condition, and measuring a first T2 distribution, performing a second NMR measurement of the sample when the sample is in a second partial saturation condition, and measuring a second T2 distribution. The method also includes separating a hydrocarbon component of the second T2 distribution from a water component of the second T2 distribution, applying a fluid substitution model to the water component of the second T2 distribution to generate a computed T2 distribution, and calculating a wettability index (WI) based on a difference between the first T2 distribution and the computed T2 distribution.

Abstract: A method of estimating a material mechanical property of a porous material, for an application or objective with a specific application frequency and application strain amplitude, includes estimating an application frequency and an application strain amplitude for use in a targeted application or objective, and constructing a frequency transfer function relating the material mechanical property to measurement frequencies, the measurement frequency range including a measurement frequency different from the application frequency.

Abstract: Examples described herein provide a computer-implemented method for deriving textual properties of a reservoir formation. The method includes acquiring multi-frequency dielectric data (?meas). The method further includes applying a dielectric mixing model between different fluid phases to generate an effective fluid permittivity (?fluid) by mixing the permittivity of water and hydrocarbon fluids. The method further includes applying the dielectric mixing model between the effective fluid permittivity (?fluid) and a matrix permittivity (?m). The method further includes minimizing a difference between a measured dielectric response and the dielectric mixing model by optimizing model parameters. The method further includes computing a cementation exponent (m) and a saturation exponent (n) from the multi-frequency dielectric data (?meas). The method further includes estimating a formation property based at least in part on the cementation exponent (m) and the saturation exponent (n).

Abstract: A method of estimating a material mechanical property of a porous material, for an application or objective with a specific application frequency and application strain amplitude, includes estimating an application frequency and an application strain amplitude for use in a targeted application or objective, and constructing a frequency transfer function relating the material mechanical property to measurement frequencies, the measurement frequency range including a measurement frequency different from the application frequency.

Abstract: A method of estimating properties of a resource bearing formation includes receiving, by a processor, a measured echo train generated by a nuclear magnetic resonance (NMR) measurement device deployed in a region of interest, and a measured noise of the measured echo train, and calculating a T2 distribution subject to a nonlinear equality constraint, the nonlinear equality constraint dependent on the measured noise and a fitting error between the measured echo train and a modeled echo train. Calculating the T2 distribution includes estimating a solution for the T2 distribution that is closest to satisfying the nonlinear equality constraint.

Abstract: A method for transforming an earth formation and/or production equipment based on correcting nuclear magnetic resonance (NMR) data to account for partially water-saturated rock includes: receiving NMR logging data having echo-trains for an earth formation; inverting the echo-trains to provide transverse relaxation time constant (T2) distributions for various components of fluid in the earth formation; substituting a T2 distribution for mobile water of fully water-saturated rock for a T2 distribution for mobile water of partially water-saturated rock based on values of the mobile water T2 distribution of partially water-saturated rock and a total porosity constraint; summing the T2 distribution for mobile water of fully water-saturated rock and a T2 distribution for an immobile water component of the fluid to provide a T2, distribution for fully water-saturated rock; and transforming the earth formation and/or the production equipment based on a parameter derived from the T2 distribution for fully water-satura

Abstract: Systems and methods to evaluate a formation by analyzing drill cuttings involve a multi-frequency dielectric coaxial probe to obtain a reflected voltage from a medium under test based on a reference voltage over a frequency range. The medium under test includes the drill cuttings. The system includes a processor to compute an effective permittivity of the drill cuttings over the frequency range based on a reflection coefficient, which is a ratio of the reflected voltage to the reference voltage over the frequency range, and to determine one or more parameters from the effective permittivity. The one or more parameters are used to make decisions about subsequent drilling in the formation.

Abstract: A method of estimating properties of a resource bearing formation includes receiving, by a processor, a measured echo train generated by a nuclear magnetic resonance (NMR) measurement device deployed in a region of interest, and a measured noise of the measured echo train, and calculating a T2 distribution subject to a nonlinear equality constraint, the nonlinear equality constraint dependent on the measured noise and a fitting error between the measured echo train and a modeled echo train. Calculating the T2 distribution includes estimating a solution for the T2 distribution that is closest to satisfying the nonlinear equality constraint.

Abstract: An apparatus for estimating fracture properties of a resource bearing formation includes a nuclear magnetic resonance (NMR) measurement device configured to be deployed in a region of interest including a tight rock formation region, the NMR measurement device including a transmitting assembly configured to transmit an NMR pulse sequence into the tight rock formation region, a receiving assembly configured to detect NMR signals corresponding to a response of the formation region to the pulse sequence, and a processor configured to receive the NMR signals. The processor is configured to invert the NMR signals into a transverse relaxation time (T2) distribution, separate the T2 distribution based on a cut-off time into a first volumetric indicative of matrix and pore responses and a second volumetric indicative of fracture responses, estimate a pore size distribution based on the second volumetric, and calculate a fracture aperture size distribution based on the pore diameter.

Abstract: A method for transforming an earth formation and/or production equipment based on correcting nuclear magnetic resonance (NMR) data to account for partially water-saturated rock includes: receiving NMR logging data having echo-trains for an earth formation; inverting the echo-trains to provide transverse relaxation time constant (T2) distributions for various components of fluid in the earth formation; substituting a T2 distribution for mobile water of fully water-saturated rock for a T2 distribution for mobile water of partially water-saturated rock based on values of the mobile water T2 distribution of partially water-saturated rock and a total porosity constraint; summing the T2 distribution for mobile water of fully water-saturated rock and a T2 distribution for an immobile water component of the fluid to provide a T, distribution for fully water-saturated rock; and transforming the earth formation and/or the production equipment based on a parameter derived from the T2 distribution for fully water-saturat

Abstract: The stability of subterranean, laminated, carbonate-containing formations that have strongly hydrophilic-wet surfaces is improved by introducing into the formation an aqueous fluid having dispersed therein relative permeability modifiers (RPMs). The RPMs are designed to enter the fractures and gaps between the layers in the formation and alter their surface wettability to inhibit water from further entering into the shale rock, thereby improving stability.

Abstract: A system and method for estimating a fluid loss in a borehole while drilling are disclosed. A drill string disposed in the borehole. A first sensor of the drill string is configured to obtain a first fluid parameter measurement at a first location along the drill string. A second sensor of the drill string is configured to obtain a second fluid parameter measurement at a second location axially separated from the first location. A processor estimates a fluid loss along the drill string using the first fluid parameter measurement and the second fluid parameter measurement performs an action in response to the estimated fluid loss.