Method of displacing fluids within a gas-condensate reservoir

• US 4,635,721 A
• Filed: 10/21/1985
• Issued: 01/13/1987
• Est. Priority Date: 11/29/1983
• Status: Expired due to Term

• Current Assignee: Amoco Corporation Chicago Illinois
• Original Assignee: Amoco Corporation (BP PLC)
• Inventors: Sheffield, Miller, Calvin, James W., Chaback, Joseph J., Metcalfe, Robert S.
• Primary Examiner(s): Novosad, Stephen J.
• Application Number:
  US06/789,869
• Time in Patent Office: 449 Days
• Field of Search: 166/268, 166/273, 166/274, 166/275, 166/305.1
• US Class Current: 166/268
• CPC Class Codes: E21B 43/168 Injecting a gaseous medium

Abstract

A method is disclosed of displacing reservoir fluids through a subterranean retrograde or gas-condensate reservoir wherein a displacement fluid is introduced into the reservoir and it is displaced along with the reservoir fluids through the reservoir. The displacement fluid can be inherently miscible with the reservoir fluids at the temperture and pressure of the reservoir and comprises a nonoxidizing gas selected from a group consisting of carbon dioxide, flue gas, nitrogen, residue gas, and mixtures thereof in selected proportions.

Claims

1. A method of displacing reservoir fluids through a subterranean retrograde or gas-condensate reservoir, comprising:

introducing a displacement fluid into the reservoir and displacing it and the reservoir fluids through the reservoir;

wherein the displacement fluid is inherently miscible with the reservoir fluids at the temperature and pressure of the reservoir; and

further wherein the displacement fluid comprises a nonoxidizing gas selected from the group consisting of carbon dioxide, flue gas, nitrogen, residue gas, and mixtures thereof.

2. The method of claim 1 wherein the displacement fluid comprises carbon dioxide and residue gas.

3. The method of claim 1 wherein the residue gas is a dry gas produced from the reservoir.

4. The method of claim 1 wherein the reservoir pressure is below the dew point of the reservoir fluids.

5. The method of claim 1 wherein the displacement fluid comprises at least about 50 volume percent of the fluid produced from the reservoir.

6. The method of claim 1 wherein a first portion of the displacement fluid is equivalent to at least about 1 volume percent of the hydrocarbon pore volume of the reservoir and further comprises at least about 50 volume percent of fluids produced from the reservoir.

7. A method of inhibiting in-situ condensation of reservoir fluids in a retrograde or gas condensate reservoir, comprising:

injecting a displacement fluid inherently miscible with the reservoir fluids at the temperature and pressure of the reservoir, in an amount sufficient to maintain the reservoir pressure above the original dew point of the reservoir fluids, the displacement fluid comprising a nonoxidizing gas selected from the group consisting of carbon dioxide, flue gas, nitrogen, residue gas, and mixtures thereof, and

introducing a drive slug of the nonoxidizing gas used in the displacement fluid.

8. The method of claim 7 wherein the displacement fluid comprises carbon dioxide and residue gas.

9. The method of claim 7 wherein the residue gas is a dry gas produced from the reservoir.

10. A method of reversing in-situ condensation of reservoir fluids in a retrograde or gas condensate reservoir wherein the reservoir pressure is below the dew point of the original reservoir fluids, comprising:

injecting a displacement fluid inherently miscible with the reservoir fluids at the temperature and pressure of the reservoir in an amount sufficient to maintain the reservoir pressure at or above the dew point of the reservoir retrograde fluids, and mixtures of the displacing gas and the retrograde fluids, the displacement fluid comprising a nonoxidizing gas selected from the group consisting of carbon dioxide, flue gas, nitrogen, residue gas, and mixtures thereof, and

introducing a drive slug of the nonoxidizing gas used in the displacement fluid.

11. The method of claim 10 wherein the displacement fluid comprises carbon dioxide and residue gas.

12. The method of claim 10 wherein the residue gas is a dry gas produced from the reservoir.