Heat scavenging method for thermal recovery process

Patent metadata

Field	Value
Publication number	US-10851632-B2
Application number	US-201414150419-A
Country	US
Kind code	B2
Filing date	Jan 8, 2014
Priority date	Jan 8, 2013
Publication date	Dec 1, 2020
Grant date	Dec 1, 2020

Abstract

Thermal recovery of oils is improved by capturing waste heat from a depleted steam chamber using steam plus foam and an optional gas to carry low quality steam deep into the chamber where the waste heat converts water to steam in situ. Thus, overall steam generation needs and thus costs are reduced.

First claim

What is claimed is:

1. A method of producing heavy oil, comprising:
providing a horizontal injection well in a reservoir over a horizontal production well in said reservoir and in fluid communication with said injection well;
injecting a composition into said injection well, said composition comprising a low density foam for heat scavenging (FHS) and for carrying water via buoyancy forces, wherein said FHS comprises methane gas, steam, an alcohol co-solvent, and a foaming agent, wherein the FHS has a density between 0.000598-0.0770 g/cm 3 at reservoir conditions;
producing steam in situ from said FHS to transfer heat from said reservoir to the heavy oil; and
collecting a heavy oil from said production well.

2. The method of claim 1 , wherein the foaming agent is a thermally and chemically stable surfactant at reservoir conditions.

3. The method of claim 1 , wherein the foaming agent is a non-ionic, anionic, cationic, amphoteric or zwitterionic surfactant.

4. The method of claim 1 , wherein the foaming agent is an alkaline metal carbonate or an alkaline metal hydroxide.

5. The method of claim 1 , wherein the foaming agent is selected from the group consisting of aromatic sulfonates, alkyl benzyl sulfonates, olefin sulfonates, alkyl aryl sulfonates, alkoxy sulfates, alkaline metal carbonates, alkaline metal bicarbonates, alkaline metal hydroxides, sodium carbonate, sodium bicarbonate, sodium hydroxide, potassium carbonate, potassium bicarbonate, potassium hydroxide, magnesium carbonate and calcium carbonate.

6. The method of claim 1 , wherein said methane gas further comprises air, oxygen, hydrogen, nitrogen, carbon dioxide, carbon monoxide, hydrogen sulfide, propane, butane, natural gas, flue gas, or natural gas liquids containing propane, butane, or hexane.

7. An improved method of steam assisted gravity drainage (SAGD) production of oil, comprising injecting steam into a horizontal injection well and recovering produced hydrocarbons from a lower horizontal production well, the improvement comprising injecting steam into said injection well until a steam to oil ratio (SOR) begins to increase past an economic limit of production, and then injecting a low density, said foam comprising lower quality steam, an alcohol co-solvent, a foaming agent, plus a gas comprising methane, said foam having a density between 0.000598-0.0770 g/cm 3 at reservoir conditions, wherein said method reduces an overall cumulative SOR as compared to steam injection alone.

8. The method of claim 7 , wherein said gas further comprises air, oxygen, hydrogen, nitrogen, carbon dioxide, carbon monoxide, hydrogen sulfide, propane, butane, natural gas, flue gas, or natural gas liquids containing propane, butane, or hexane.

Assignees

• Conocophillips Co

Inventors

• Brown David A
• Wickramdthilaka Siluni L
• Warren Logan A
• Wheeler Thomas J
• Govind Pradeep A

Classifications

• E21B43/2408 Primary

  SAGD in combination with other methods · CPC title

• E21B43/16

  Enhanced recovery methods for obtaining hydrocarbons · CPC title

• C09K8/592

  Compositions used in combination with generated heat, e.g. by steam injection · CPC title

• C09K8/94

  Foams · CPC title