Methods of estimating permeability of reservoir rocks using mercury injection capillary pressure can include: receiving mercury injection capillary pressure test data and porosity data for a core sample; determining a fractal dimension (D) for the core sample based on the received mercury injection capillary pressure test data for the core sample; determining a pore throat radius (R.sub.d) for the core sample; determining a composite parameter (β) for the core sample where $\beta =\frac{\varnothing R_d}{\left(D-2\right)};$
and estimating permeability (K) of the core sample based on a relationship of ln(K) as a function of ln(β) determined by performing a regression analysis data from other core samples from the reservoir.

A method of determining absolute permeability in carbonates without upscaling computations includes performing a nuclear magnetic resonance (NMR) analysis and a mercury-injection capillary-pressure (MICP) analysis on at least three samples from carbonate rock of a set of representative regions to determine an experimental permeability, where each of the representative regions have properties related to the porosity and pore-throat size of the carbonate rock. A series of low resolution X-ray scans and a series of high resolution X-ray scans are performed on the same three samples of the carbonate rock of the set of representative regions. Permeability simulations are performed on the same three samples of the carbonate rock of the set of representative regions to determine a computed permeability. The experimental permeability and the computed permeability are then compared to provide computationally manageable and reasonable estimates of the absolute permeability of the carbonate rock.

The present disclosure relates, according to some embodiments, to methods of marker based direct integrity testing of at least one membrane comprising: (a) dosing a feed fluid of a loop with at least one marker comprising at least one challenge particle, the loop comprising: the feed fluid; a pump comprising an outlet stream; a membrane module comprising the at least one membrane and a membrane module outlet stream, wherein the membrane module is in fluid communication with the outlet stream; a marker recycle stream in fluid communication with the membrane module outlet stream and the pump; and a means to measure particle concentrations; (b) circulating the feed fluid through the membrane module at least once to produce a filtrate comprising a filtered at least one marker; (c) measuring a filtrate particle concentration of the filtered at least one filtered marker in the filtrate to produce a filtrate concentration measurement; and (d) calculating a log removal value from the filtrate concentration measurement and the feed concentration measurement; wherein the log removal value is less than about 3 μm.

Methods of estimating permeability of reservoir rocks using mercury injection capillary pressure can include: receiving mercury injection capillary pressure test data and porosity data for a core sample; determining a fractal dimension (D) for the core sample based on the received mercury injection capillary pressure test data for the core sample; determining a pore throat radius (R.sub.d) for the core sample; determining a composite parameter (β) for the core sample where

[00001]$\beta =\frac{\varnothing R_d}{\left(D-2\right)};$

and estimating permeability (K) of the core sample based on a relationship of ln(K) as a function of ln(β) determined by performing a regression analysis data from other core samples from the reservoir.

A method of determining absolute permeability in carbonates without upscaling computations includes performing a nuclear magnetic resonance (NMR) analysis and a mercury-injection capillary-pressure analysis on at least three samples from the carbonate rock to determine an experimental permeability. A series of low resolution X-ray scans and a series of high resolution X-ray scans are performed to determine a set of representative regions, wherein each of the representative regions reflects properties related to the porosity and pore-throat size of the carbonate rock. Permeability simulations are performed on the set of representative regions to determine a computed permeability. The experimental permeability and the computed permeability are compared to demonstrate that the set of representative regions provide computationally manageable and reasonable estimates of the permeability of the carbonate rock.

The present disclosure relates, according to some embodiments, to methods of marker based direct integrity testing of at least one membrane comprising: (a) dosing a feed fluid of a loop with at least one marker comprising at least one challenge particle, the loop comprising: the feed fluid; a pump comprising an outlet stream; a membrane module comprising the at least one membrane and a membrane module outlet stream, wherein the membrane module is in fluid communication with the outlet stream; a marker recycle stream in fluid communication with the membrane module outlet stream and the pump; and a means to measure particle concentrations; (b) circulating the feed fluid through the membrane module at least once to produce a filtrate comprising a filtered at least one marker; (c) measuring a filtrate particle concentration of the filtered at least one filtered marker in the filtrate to produce a filtrate concentration measurement; and (d) calculating a log removal value from the filtrate concentration measurement and the feed concentration measurement; wherein the log removal value is less than about 3 m.

The present disclosure relates, according to some embodiments, to methods of marker based direct integrity testing of at least one membrane comprising: (a) dosing a feed fluid of a loop with at least one marker comprising at least one challenge particle, the loop comprising: the feed fluid; a pump comprising an outlet stream; a membrane module comprising the at least one membrane and a membrane module outlet stream, wherein the membrane module is in fluid communication with the outlet stream; a marker recycle stream in fluid communication with the membrane module outlet stream and the pump; and a means to measure particle concentrations; (b) circulating the feed fluid through the membrane module at least once to produce a filtrate comprising a filtered at least one marker; (c) measuring a filtrate particle concentration of the filtered at least one filtered marker in the filtrate to produce a filtrate concentration measurement; and (d) calculating a log removal value from the filtrate concentration measurement and the feed concentration measurement; wherein the log removal value is less than about 3 m.

An isotope nuclear magnetic method for analyzing ineffective water absorption of rock pores includes steps of: saturating core pores of a core sample with a wetting phase fluid of water H.sub.2O, and obtaining a core T.sub.2 spectrum after being saturated with the water; re-saturating the core pores with a wetting phase fluid of heavy water D.sub.2O, and obtaining a rock baseline T.sub.2 spectrum; injecting fluorinated oil into the core sample saturated with the heavy water; injecting the water H.sub.2O, simulating a water injection process, and injecting the fluorinated oil, so as to analyze a content of immobile water and obtain a residual T.sub.2 spectrum, wherein a range formed by a difference between the residual T.sub.2 spectrum and the rock baseline T.sub.2 spectrum is an ineffective water absorption portion of the rock pores, and an ineffective water absorption amount is obtained.

The disclosure relates to methods for determining imbibition of hydraulic fracturing fluids into hydrocarbon-bearing formations. More specifically, the disclosure relates to laboratory methods for determining certain unconventional flow parameters to measure the imbibition over time of hydraulic fracturing fluids into a low-permeability hydrocarbon-bearing rock formation.

The present disclosure relates, according to some embodiments, to methods of marker based direct integrity testing of at least one membrane comprising: (a) dosing a feed fluid of a loop with at least one marker comprising at least one challenge particle, the loop comprising: the feed fluid; a pump comprising an outlet stream; a membrane module comprising the at least one membrane and a membrane module outlet stream, wherein the membrane module is in fluid communication with the outlet stream; a marker recycle stream in fluid communication with the membrane module outlet stream and the pump; and a means to measure particle concentrations; (b) circulating the feed fluid through the membrane module at least once to produce a filtrate comprising a filtered at least one marker; (c) measuring a filtrate particle concentration of the filtered at least one filtered marker in the filtrate to produce a filtrate concentration measurement; and (d) calculating a log removal value from the filtrate concentration measurement and the feed concentration measurement; wherein the log removal value is less than about 3 m.