Workflow for resaturation and analysis of unconventional core samples

1. A method for testing an unconventional core sample, the method comprising:

loading the unconventional core sample into a sample holder;

introducing fluid into the sample holder at an elevated pressure such that fluid is injected into the internal pore space of the unconventional core sample in order to resaturate the unconventional core sample with the fluid, wherein the fluid is selected from the group including a hydrocarbon fluid and a water-based formation fluid; and

performing analysis on the unconventional core sample resaturated with fluid at the elevated pressure, wherein the analysis derives physical properties of a reservoir rock from which the unconventional core sample was obtained, wherein the physical properties derived from the analysis include at least one property that particularly relates to organic pore space of the reservoir rock that holds producible hydrocarbons;

wherein the elevated pressure is selected according to at least one of pore size of the unconventional core sample and capillary pressure of the unconventional core sample.

2. The method of claim 1 , wherein the elevated pressure is at least 2,000 psig (140.6 kg/square cm gauge).

3. The method of claim 1 , further comprising performing analysis on the unconventional core sample resaturated with fluid at elevated pressure, wherein the analysis derives geomechanical and geochemical properties of the reservoir rock from which the unconventional core sample was obtained, wherein the analysis utilizes multidimensional NMR experiments that acquires multidimensional NMR data (T 1 , T 2 , D).

4. The method of claim 1 , wherein

the fluid is a hydrocarbon fluid.

5. The method of claim 4 , wherein the at least one property that particularly relates to organic pore space of the reservoir rock that holds producible hydrocarbons is selected from the group including organic porosity of the reservoir rock that holds producible hydrocarbons, wettability of the organic pore space of the reservoir rock that holds producible hydrocarbons, pore pressure of the organic pore space of the reservoir rock that holds producible hydrocarbons, and hydrocarbon saturation of the organic pore space of the reservoir rock that holds producible hydrocarbons.

6. The method of claim 4 , wherein the physical properties derived from the analysis further include at least one property that particularly relates to inorganic pore space of the reservoir rock that holds producible hydrocarbons.

7. The method of claim 6 , wherein the at least one property that particularly relates to inorganic pore space of the reservoir rock that holds producible hydrocarbons is selected from the group including inorganic porosity of the reservoir rock that holds producible hydrocarbons, wettability of the inorganic pore space of the reservoir rock that holds producible hydrocarbons, pore pressure of the inorganic pore space of the reservoir rock that holds producible hydrocarbons, and hydrocarbon saturation of the inorganic pore space of the reservoir rock that holds producible hydrocarbons.

8. The method of claim 4 , wherein the hydrocarbon fluid is obtained from the reservoir rock from which the unconventional core sample was obtained.

9. The method of claim 1 , wherein:

the fluid is a water-based formation fluid; and

the physical properties derived from the analysis include at least one property that particularly relates to inorganic pore space of the reservoir rock that holds producible water-based formation fluid.

10. The method of claim 9 , wherein the at least one property that particularly relates to inorganic pore space of the reservoir rock that holds producible water-based formation fluid is selected from the group including inorganic porosity of the reservoir rock that holds producible water-based formation fluid, wettability of the inorganic pore space of the reservoir rock that holds producible water-based formation fluid, pore pressure of the inorganic pore space of the reservoir rock that holds producible water-based formation fluid, and water saturation of the inorganic pore space of the reservoir rock that holds producible water-based formation fluid.

11. The method of claim 9 , wherein the water-based formation fluid is brine having a salinity that matches salinity of brine held by the reservoir rock from which the unconventional core sample was obtained.

12. The method of claim 1 , wherein the analysis utilizes multidimensional NMR experiments that acquires multidimensional NMR data (T 1 , T 2 , D).

13. A method for testing unconventional core samples, the method comprising:

loading a first unconventional core sample into a sample holder;

introducing a hydrocarbon fluid into the sample holder at an elevated pressure such that hydrocarbon fluid is injected into the internal pore space of the first unconventional core sample in order to resaturate the first unconventional core sample with the hydrocarbon fluid;

performing analysis on the first unconventional core sample resaturated with hydrocarbon fluid at the elevated pressure, wherein the analysis derives physical properties of a reservoir rock from which the first unconventional core sample was obtained, wherein the physical properties derived from the analysis include at least one property that particularly relates to organic pore space of the reservoir rock that holds producible hydrocarbons;

loading a second unconventional core sample into a sample holder, wherein the second unconventional core sample is obtained from the same reservoir rock as the first unconventional core sample;

introducing a water-based formation fluid into the sample holder at an elevated pressure such that the water-based formation fluid is injected into the internal pore space of the second unconventional core sample in order to resaturate the second unconventional core sample with the water-based formation fluid; and

performing analysis on the second unconventional core sample resaturated with water-based formation fluid at the elevated pressure, wherein the analysis derives physical properties of the reservoir rock from which the second unconventional core sample was obtained, wherein the physical properties derived from the analysis include at least one property that particularly relates to inorganic pore space of the reservoir rock that holds producible water-based formation fluids;

wherein the analysis performed on both the first and second unconventional core samples utilizes multidimensional NMR experiments that acquires multidimensional NMR data (T 1 , T 2 , D).

14. The method of claim 13 , wherein the physical properties derived from the analysis performed on the first unconventional core sample further include at least one property that particularly relates to inorganic pore space of the reservoir rock that holds producible hydrocarbons.

15. The method of claim 13 , wherein:

the elevated pressure is selected according to at least one of pore size of the first and second unconventional core samples and capillary pressure of the first and second unconventional core samples; and/or

said elevated pressure is at least 2,000 psig (140.6 kg/square cm gauge).

16. A method for testing an unconventional core sample, the method comprising:

loading an unconventional core sample into a sample holder;

introducing a hydrocarbon fluid into the sample holder at an elevated pressure such that the hydrocarbon fluid is injected into the internal pore space of the unconventional core sample in order to resaturate the unconventional core sample with the hydrocarbon fluid;

performing analysis on the unconventional core sample resaturated with hydrocarbon fluid at the elevated pressure, wherein the analysis derives physical properties of a reservoir rock from which the unconventional core sample was obtained, wherein the physical properties derived from the analysis include at least one property that particularly relates to organic pore space of the reservoir rock that holds producible hydrocarbons;

introducing a water-based formation fluid into the sample holder at an elevated pressure such that the water-based formation fluid is injected into the internal pore space of the unconventional core sample in order to resaturate the unconventional core sample with the water-based formation fluid; and

performing analysis on the unconventional core sample resaturated with water-based formation fluid at the elevated pressure, wherein the analysis derives physical properties of the reservoir rock from which the unconventional core sample was obtained, wherein the physical properties derived from the analysis include at least one property that particularly relates to inorganic pore space of the reservoir rock that holds producible water-based formation fluids;

wherein the analysis performed on both the first and second unconventional core samples utilizes multidimensional NMR experiments that acquires multidimensional NMR data (T 1 , T 2 , D).

17. The method of claim 16 , wherein the physical properties derived from the analysis performed on the unconventional core sample resaturated with hydrocarbon fluid further include at least one property that particularly relates to inorganic pore space of the reservoir rock that holds producible hydrocarbons.

18. The method of claim 16 , wherein:

the elevated pressure is selected according to at least one of pore size of the unconventional core sample and capillary pressure of the unconventional core sample; and/or

the elevated pressure is at least 2,000 psig (140.6 kg/square cm gauge).