A shale oil analysis method and apparatus for continuously characterizing saturation of adsorbed oil and free oil, comprising: obtain NMR T2 spectrum, NMR porosity, oil saturation and wettability indexes of a core samples, determine a lower limit value for the saturation calculation of the absorbed oil based on the NMR T2 spectrum, the NMR porosity, the oil saturation and wettability indices; determining a lower limit value for the saturation calculation of the free oil according to the bulk relaxation T.sub.2 spectrum of the crude oil of the well interval or an adjacent well interval and the NMR T.sub.2 spectrum of the core samples; calculating the saturation of the absorbed oil and the free oil, and analyzing the shale oil in the well interval to be analyzed. The solution realizes the quantitative and continuous characterization of the adsorbed oil and the free oil of the shale oil via well logs.

A method for rapid wettability evaluation during exploratory drilling of a hydrocarbon. The method include pre-saturation of the sample by a brine, measuring the bulk brine's T.sub.2 NMR relaxation parameter, expelling the brine by oil in the sample, measuring the oil's bulk and pore T.sub.2 NMR relaxation parameter, measuring the brine's non-reducible content and T.sub.2 NMR relaxation parameter of water in the presence of dominant oil content, expelling the oil by the brine and measuring the T.sub.2 NMR relaxation parameter of the irreducible oil content in the dominant brine. The measurements are combined in the index:
I=[(T.sub.2WB−T.sub.2WIOIRR)/T.sub.2WB]−[(T.sub.2OB−T.sub.2OIWIRR)/T.sub.2OB], where WB is water bulk, OB is oil bulk, WIOIRR—injected pore water at the irreducible oil content, OIWIRR—injected pore oil at the irreducible water content.

A method for rapid wettability evaluation during exploratory drilling of a hydrocarbon. The method include pre-saturation of the sample by a brine, measuring the bulk brine's T.sub.2 NMR relaxation parameter, expelling the brine by oil in the sample, measuring the oil's bulk and pore T.sub.2 NMR relaxation parameter, measuring the brine's non-reducible content and T.sub.2 NMR relaxation parameter of water in the presence of dominant oil content, expelling the oil by the brine and measuring the T.sub.2 NMR relaxation parameter of the irreducible oil content in the dominant brine. The measurements are combined in the index:
I=[(T.sub.2WB−T.sub.2WIOIRR)/T.sub.2WB]−[(T.sub.2OB−T.sub.2OIWIRR)/T.sub.2OB], where WB is water bulk, OB is oil bulk, WIOIRR—injected pore water at the irreducible oil content, OIWIRR—injected pore oil at the irreducible water content.

In one non-limiting embodiment, the present disclosure is directed to a controller having a memory; and a processor coupled to the memory and configured to: cause a neural network to receive current measurements of a current material; instruct the neural network to determine dominant features of the current measurements; instruct the neural network to provide the dominant features to a decoder; and instruct the decoder to generate a generated spectral response of the current material based on the dominant features. In another non-limiting embodiment, the present disclosure is directed to a method including the steps of receiving current measurements of a current material; determining dominant features of the current measurements; providing the dominant features; and generating a generated spectral response of the current material based on the dominant features.

In one non-limiting embodiment, the present disclosure is directed to a controller having a memory; and a processor coupled to the memory and configured to: cause a neural network to receive current measurements of a current material; instruct the neural network to determine dominant features of the current measurements; instruct the neural network to provide the dominant features to a decoder; and instruct the decoder to generate a generated spectral response of the current material based on the dominant features. In another non-limiting embodiment, the present disclosure is directed to a method including the steps of receiving current measurements of a current material; determining dominant features of the current measurements; providing the dominant features; and generating a generated spectral response of the current material based on the dominant features.

Systems, methods, and apparatuses for determining pore volume and pore volume compressibility of secondary porosity in rock samples is disclosed. In some implementations, determining a pore volume of a secondary porosity in a rock core sample may include saturating the rock sample with deuterium oxide (D2O) by applying a vacuum to the core sample covered by D2O; centrifuging the saturated rock sample at a selected rotational speed in the presence of a second fluid to displace a portion of the D2O from the rock sample with the second fluid; measuring the rock sample with low-field .sup.1 H nuclear magnetic resonance (NMR) to determine a volume of the second fluid within the rock sample; and determining a pore volume associated with a secondary porosity based on the volume of the second fluid within the rock sample.

Systems, methods, and apparatuses for determining pore volume and pore volume compressibility of secondary porosity in rock samples is disclosed. In some implementations, determining a pore volume of a secondary porosity in a rock core sample may include saturating the rock sample with deuterium oxide (D2O) by applying a vacuum to the core sample covered by D2O; centrifuging the saturated rock sample at a selected rotational speed in the presence of a second fluid to displace a portion of the D2O from the rock sample with the second fluid; measuring the rock sample with low-field .sup.1 H nuclear magnetic resonance (NMR) to determine a volume of the second fluid within the rock sample; and determining a pore volume associated with a secondary porosity based on the volume of the second fluid within the rock sample.

Provided is a local slice selective T.sub.2 nuclear magnetic resonance (NMR) test procedure that includes: (1) identifying a location of a fracture within a core plug; (2) conducting an initial local slice selective T.sub.2 NMR test on a slice of the plug that corresponds to the location to generate initial T.sub.2 measurements; (3) determining an initial fracture pore volume of the fracture based on the initial T.sub.2 measurements; (4) conducting an in-situ local slice selective T.sub.2 NMR test on the slice of the plug to generate in-situ T.sub.2 measurements and corresponding measures of a volume of fluid expelled from the plug; (5) determining an in-situ fracture pore volume for the fracture based on the in-situ T.sub.2 measurements; and (6) comparing the volume of water to a difference between the initial and the in-situ fracture pore volumes to confirm the accuracy of the in-situ pore volume.

Provided is a local slice selective T.sub.2 nuclear magnetic resonance (NMR) test procedure that includes: (1) identifying a location of a fracture within a core plug; (2) conducting an initial local slice selective T.sub.2 NMR test on a slice of the plug that corresponds to the location to generate initial T.sub.2 measurements; (3) determining an initial fracture pore volume of the fracture based on the initial T.sub.2 measurements; (4) conducting an in-situ local slice selective T.sub.2 NMR test on the slice of the plug to generate in-situ T.sub.2 measurements and corresponding measures of a volume of fluid expelled from the plug; (5) determining an in-situ fracture pore volume for the fracture based on the in-situ T.sub.2 measurements; and (6) comparing the volume of water to a difference between the initial and the in-situ fracture pore volumes to confirm the accuracy of the in-situ pore volume.

A method for monitoring the oleophilic fluid to aqueous fluid ratio of a drilling fluid includes selecting a sample of the drilling fluid that has been recirculated, measuring the NMR response of the sample of the drilling fluid and determining the oleophilic fluid to aqueous fluid ratio of the drilling fluid based at least in part on the NMR response.