Effective porosity determination for tight gas formations

Patent metadata

Field	Value
Publication number	US-10174613-B2
Application number	US-201515104509-A
Country	US
Kind code	B2
Filing date	Jan 13, 2015
Priority date	Jan 14, 2014
Publication date	Jan 8, 2019
Grant date	Jan 8, 2019

Abstract

A disclosed effective porosity determination method for tight gas formations includes: obtaining a core sample sealed in a pressure-maintaining core vault during transport out of the borehole; coupling the core vault to a collection chamber; based at least in part on measured pressure, temperature, and fluid volumes in the collection chamber, deriving the number of moles of gas retrieved with the core sample; and combining the number of moles with a downhole pressure, a downhole temperature, and a downhole core sample volume to determine an effective porosity of the tight gas formation. A system embodiment includes: a coring tool having a core vault with a seal to provide pressure-preserved transport of a core sample from a tight gas formation; a collection chamber that attaches to the core vault to measure volumes of fluids and gas; and a processing unit that responsively determines an effective porosity of the tight gas formation.

First claim

What is claimed is:

1. A tight gas formation effective porosity determination method that comprises:
obtaining a downhole core sample of a tight gas formation penetrated by a borehole, the core sample having been sealed in a pressure-maintaining core vault during transport out of the borehole;
coupling the core vault to a collection chamber;
based at least in part on measured pressure, temperature, and fluid volumes in the collection chamber, deriving a number of moles of gas retrieved with the core sample, wherein the deriving comprises:
determining a gas volume of the collection chamber; and
adding the collection chamber gas volume to an effective pore space of the core sample and to a space around the core sample in the core vault to obtain a total gas volume; and

combining the number of moles together with a downhole pressure, a downhole temperature, and a downhole core sample volume to determine an effective porosity of the tight gas formation.

2. The method of claim 1 , wherein the combining includes calculating a gas volume in the core sample during a coring operation.

3. The method of claim 2 , wherein the downhole temperature is a measured mud temperature during coring, and the downhole pressure is a hydrostatic borehole pressure during coring.

4. The method of claim 2 , wherein the combining further includes determining the effective porosity based at least in part on the gas volume, a reservoir temperature, and a reservoir pressure, while accounting for a compressibility of the gas volume and a compressibility of core sample material.

5. The method of claim 4 , further comprising obtaining the reservoir temperature from a borehole log.

6. The method of claim 4 , further comprising measuring pressure of a formation more porous than the tight gas formation and performing hydrostatic extrapolation to determine said reservoir pressure.

7. The method of claim 1 , wherein the deriving further comprises:
determining a gas compressibility based at least in part on a measured density or molecular weight of gas in the collection chamber; and
combining the compressibility with the total gas volume and equilibrium pressure and equilibrium temperature to get the number of moles of gas retrieved with the core sample.

8. The method of claim 1 , wherein measuring one or more liquid volumes includes finding a volume and compressibility for each of: a mud filtrate, a coring fluid, and water.

9. A tight gas formation effective porosity determination system that comprises:
a coring tool having a core vault with a seal to provide pressure-preserved transport, the core vault receiving a core sample from a tight gas formation;
a collection chamber that attaches to the core vault to receive and measure volumes of fluids and gas from the core sample; and
a processing unit that, based at least in part on said volumes and a downhole pressure and a downhole temperature, determines an effective porosity of the tight gas formation, wherein:
as part of determining the effective porosity, the processing unit calculates a gas volume in the core sample during a coring operation;
as part of calculating the gas volume, the processing unit derives a number of moles of gas retrieved with the core sample; and
as part of said deriving, the processing unit adds a gas volume of the collection chamber to an effective pore space of the core sample and to a space around the core sample in the core vault to obtain a total gas volume.

10. The system of claim 9 , wherein the downhole temperature is a measured mud temperature during coring, and the downhole pressure is a hydrostatic borehole pressure during coring.

11. The system of claim 9 , wherein the processing unit determines the effective porosity based at least in part on the gas volume, a reservoir temperature, and a reservoir pressure, while accounting for a compressibility of the gas volume and a compressibility of core sample material.

12. The system of claim 9 , wherein as part of said deriving, the processing unit combines the total gas volume with a gas compressibility, a collection chamber temperature, and a collection chamber pressure.

13. A non-transient information storage medium having software that causes a processing unit carry out an effective porosity determination method for a tight gas formation, the method comprising:
obtaining, by a logging tool, a temperature of the tight gas formation;
obtaining, by the logging tool, a pressure of the tight gas formation;
receiving, by the processing unit, pressure, volume, and temperature measurements of a gas in a collection chamber attached to a core vault having a pressure-preserved core sample from the tight gas formation;
calculating, by the processing unit, a number of moles of gas retrieved with the core sample, wherein the calculation of the number of moles comprises:
determining a gas volume of the collection chamber; and
adding the collection chamber gas volume to an effective pore space of the core sample and to a space around the core sample in the core vault to obtain a total gas volume;

combining, by the processing unit, the number of moles of gas together with the temperature and pressure of the tight gas formation and a downhole volume of the core sample to determine an effective porosity of the tight gas formation; and
displaying on a display, by the processing unit, the effective porosity.

14. The medium of claim 13 , wherein as part of said determining, the method carried out by the processing unit includes calculating a gas volume in the core sample during a coring operation.

15. The medium of claim 14 , wherein the downhole temperature is a measured mud temperature during coring, and the downhole pressure is a hydrostatic borehole pressure during coring.

16. The medium of claim 14 , wherein the method carried out by the processing unit includes determining the effective porosity based at least in part on the gas volume, a reservoir temperature, and a reservoir pressure, while accounting for a compressibility of the gas volume and a compressibility of core sample material.

Assignees

• Halliburton Energy Services Inc

Inventors

• Quintero Luis F
• Westacott Donald

Classifications

• G01N33/241

  for hydrocarbon content · CPC title

• E21B41/005

  Waste disposal systems · CPC title

• E21B25/08

  Coating, freezing, consolidating cores (E21B25/06 takes precedence); Recovering uncontaminated cores or cores at formation pressure · CPC title

• E21B49/06 Primary

  using side-wall drilling tools {pressing} or scrapers · CPC title

• E21B43/16

  Enhanced recovery methods for obtaining hydrocarbons · CPC title