Tight gas formation pressure determination method

Patent metadata

Field	Value
Publication number	US-10301936-B2
Application number	US-201515104508-A
Country	US
Kind code	B2
Filing date	Jan 13, 2015
Priority date	Jan 14, 2014
Publication date	May 28, 2019
Grant date	May 28, 2019

Abstract

A disclosed pressure determination method for tight gas formations includes: 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; determining an effective pore space of the core sample; deriving the number of moles of gas retrieved with the core sample; and combining the effective pore space and the number of moles together with a downhole temperature to get an estimated formation pressure. A system embodiment includes: a core vault that provides 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 liquid and gas fluids from the core sample; and a processing unit that determines an estimated formation pressure based on said volumes, a downhole temperature, and an effective pore space of the core sample.

First claim

What is claimed is:

1. A method for determining tight gas formation pressure, said method comprising:
extracting a downhole core sample of a tight gas formation penetrated by a borehole, said extracting including sealing the core sample in a pressure-maintaining core vault during transport out of the borehole;
measuring a porosity of the formation or the core sample;
measuring a volume of the core sample;
determining an effective pore space of the core sample based, at least in part, on the measured porosity and the measured volume of the core sample;
deriving a number of moles of gas retrieved with the core sample based, at least in part, on the effective pore space;
determining a downhole temperature; and
determining a tight gas formation pressure based on the effective pore space, the number of moles of gas retrieved with the core sample, and the downhole temperature.

2. The method of claim 1 , wherein said deriving the number of moles of gas retrieved with the core sample comprises:
connecting the core vault to a collection chamber having known content and known volume; and
measuring an equilibrium pressure and equilibrium temperature of the collection chamber after said connecting.

3. The method of claim 2 , wherein the known content is vacuum.

4. The method of claim 2 , wherein the known content is inert gas.

5. The method of claim 2 , wherein said deriving the number of moles of gas retrieved with the core sample comprises:
measuring one or more liquid volumes in the collection chamber;
determining a collection chamber gas volume based at least in part on the one or more liquid volumes and the known volume; and
adding the collection chamber gas volume to the effective pore space of the core sample and a core vault space around the core sample to obtain a total gas volume.

6. The method of claim 5 , wherein said deriving the number of moles of gas retrieved with the core sample 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
determining the number of moles of gas retrieved with the core sample based on the gas compressibility, the total gas volume, the equilibrium pressure, and the equilibrium temperature.

7. The method of claim 5 , wherein said measuring one or more liquid volumes includes determining a volume and compressibility for each of: a mud filtrate, a coring fluid, and water.

8. A system for determining tight gas formation pressure, said system comprising:
a coring device for removing a core sample from a tight gas formation;
a core vault that is sealable to provide pressure-preserved transport, the core vault configured to receive a core sample from a tight gas formation;
a logging tool configured to measure a downhole temperature;
a tool to measure a porosity of the formation or the core sample;
a collection chamber that attaches to the core vault, said collection chamber configured to receive and measure volumes of liquid and gas fluids from the core sample; and
a processing unit configured to,
determine an effective pore space of the core sample based, at least in part, on the measured porosity of the formation or the core sample and a measured volume of the core sample; and
determine a tight gas formation pressure based, at least in part, on said volumes of liquid and gas fluids, the measured downhole temperature, and the effective pore space of the core sample.

9. The system of claim 8 , wherein the processing unit determines the effective pore space by retrieving a measured porosity from a log of the tight gas formation and multiplying by the measured volume of the core sample.

10. The system of claim 8 , wherein as part of determining the formation pressure, the processing unit determines a number of moles of gas retrieved from the core sample by, in part, obtaining an equilibrium temperature and equilibrium pressure of the collection chamber after the attachment of the collection chamber to the core vault.

11. The system of claim 10 , wherein as part of determining the formation pressure, the processing unit further obtains a gas compressibility based at least in part on a measured density or molecular weight of gas in the collection chamber.

12. The system of claim 11 , wherein the processing unit combines the gas compressibility with equilibrium temperature, equilibrium pressure, and total gas volume to determine a number of moles of gas retrieved with the core sample.

13. The system of claim 12 , wherein the processing unit calculates the formation pressure based on the number of moles of gas, the effective pore space, the downhole temperature, and an estimated downhole gas compressibility.

14. The system of claim 12 , wherein the processing unit calculates the total gas volume by adding a measured collection chamber gas volume to the effective pore space of the core sample and to a core vault space around the core sample.

Assignees

• Halliburton Energy Services Inc
• Halliburton Energy Serv Inc

Inventors

• Westacott Donald
• Quintero Luis F

Classifications

• E21B49/06 Primary

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

• E21B43/16

  Enhanced recovery methods for obtaining hydrocarbons · CPC title

• E21B25/08

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

• G01N33/241

  for hydrocarbon content · CPC title

• E21B41/005

  Waste disposal systems · CPC title