Liquid carbon dioxide cleaning of wellbores and near-wellbore areas using high precision stimulation

• US 7,677,317 B2
• Filed: 12/18/2006
• Issued: 03/16/2010
• Est. Priority Date: 12/18/2006
• Status: Expired due to Fees

• Current Assignee: Conocophillips Company (ConocoPhillips)
• Original Assignee: Conocophillips Company (ConocoPhillips)
• Inventors: Wilson, Dennis R.
• Primary Examiner(s): Bates; Zakiya W.
• Application Number:
  US11/612,325
• Publication Number:
  US 20080142224A1
• Time in Patent Office: 1,184 Days
• Field of Search: None
• US Class Current: 166/308.2
• CPC Class Codes: E21B 37/06 using chemical means for preventing or limiting , e.g. eliminating, the deposition of paraffins or like substances
• CPC Class Codes: E21B 43/114 Perforators using direct fluid action on the wall to be perforated, e.g. abrasive jets
• CPC Class Codes: E21B 43/267 reinforcing fractures by propping

Abstract

The invention relates to a method to clean a wellbore and the near wellbore area adjacent to the wellbore of a hydrocarbon bearing formation adjacent to the production zone of the wellbore. The invention includes a method to clean a casing inserted into a wellbore and a method for cleaning a wellbore of fracturing fluid, with or without proppant. Each of the methods includes the steps of injecting a treatment medium comprising liquid carbon dioxide into a wellbore where pressure within the wellbore is regulated to either maintain the treatment medium in the liquid state, or allow at least a portion of the treatment medium to vaporize upon introduction into the wellbore. The treatment medium vaporizes to loosen and/or entrain undesirable materials from within the wellbore or casing and escape through the wellhead, carrying with it the undesirable materials.

Claims

1. A method for fracturing a fluid bearing formation having a wellbore comprising the steps of:

introducing a quantity of fracturing fluid into said wellbore sufficient to fracture said formation;

introducing a treatment medium comprising liquid carbon dioxide into said wellbore; and

vaporizing at least a portion of said treatment medium;

wherein the steps of introducing a quantity of fracturing fluid into said wellbore and introducing a treatment medium comprising liquid carbon dioxide into said wellbore comprise the steps of;

regulating pressure within said wellbore and said formation such that at least a portion of said treatment medium remains in a liquid state following injection into said wellbore;

inserting a length of tubing into said wellbore such that an annulus is created between said tubing and said wellbore;

pumping said treatment medium through said tubing;

pumping said fracturing fluid into said annulus;

injecting said treatment medium into said fracturing fluid to create a second fluid;

impinging said second fluid against said formation;

creating at least one fracture in said formation;

driving said second fluid into said formation; and

releasing said pressure within said wellbore.

2. The method of claim 1 wherein said fracturing fluid comprises proppant.

3. The method of claim 1 wherein the step of releasing said pressure within said wellbore vaporizes at least a portion of said second fluid, wherein said vaporized second fluid removes undesirable materials and/or water from said wellbore.

4. The method of claim 1 wherein said tubing is coiled tubing.

5. The method of claim 1 wherein the step of injecting said treatment medium into said fracturing fluid further comprises the step of injecting said treatment medium through means for focusing said treatment medium.

6. The method of claim 1 wherein said treatment medium comprising liquid carbon dioxide is introduced at a pressure of at least 2,000 psi.

7. The method of claim 1 wherein said wellbore further comprises a casing extending for at least a portion of the length of said wellbore.

8. The method of claim 1 wherein said annulus contains fracturing fluid, further comprising the steps of:

circulating additional said treatment medium down said tubing such that it exits said tubing at a first position;

vaporizing at least a portion of said treatment medium; and

driving said fracturing fluid from said annulus.

9. The method of claim 8 further comprising the steps of:

inserting additional said tubing into said wellbore such that said treatment medium exits said tubing at a second position which is deeper in said wellbore than said first position;

repeating said steps of circulating additional said treatment medium, vaporizing at least a portion of said treatment medium, and driving said fluid from said annulus; and

repeating said steps of inserting additional said tubing and circulating additional said treatment medium, vaporizing at least a portion of said treatment medium, and driving said fluid from said annulus until said formation pressure is sufficient to overcome said hydraulic head of said fluid in said annulus.