Compositions and methods for breaking a viscosity increasing polymer at very low temperature used in downhole well applications

Abstract

A composition for treating a portion of a wellbore or a portion of a subterranean formation is provided, the composition comprising: (a) water; (b) a source of hydrogen peroxide, and (c) an activator for the source of hydrogen peroxide; wherein the pH of the composition is adjusted to be within an appropriate range for the type of activator. A method for treating a portion of a wellbore or a portion of a subterranean formation, the method comprising the steps of: forming or providing a composition comprising: (a) water; (b) a source of hydrogen peroxide, and (c) an activator for the source of hydrogen peroxide; wherein the pH of the composition is adjusted within an appropriate range for the type of activator; and introducing the composition through a wellbore to treat a portion of a wellbore or a portion of a subterranean formation. The activator can be a water-soluble alkanoyl-donor compound or a chelated transition metal. Preferably, the composition further comprises an iron chelating agent. The composition and method are adapted for breaking a viscosity increasing polymer, such as xanthan. The method has particular applications where the static temperature of the portion of the wellbore or the portion of the subterranean formation to be treated is less than 100° F. (38° C.).

Description

CROSS-REFERENCE TO RELATED APPLICATIONS[0001]Not applicableSTATEMENT REGARDING FEDERALLY SPONSORED RESEARCH OR DEVELOPMENT[0002]Not ApplicableREFERENCE TO A MICROFICHE APPENDIX[0003]Not applicableBACKGROUND[0004]Hydrocarbons (e.g., oil and natural gas) in a hydrocarbon-bearing zone of a subterranean formation can be reached by drilling a wellbore into the earth, either on land or under the sea that penetrates into the hydrocarbon-bearing formation. Such a wellbore can be used to produce hydrocarbons or as an injector well to inject a fluid, e.g., water or gas, to drive the relevant fluids / gasses into a production wellbore. Typically, such a wellbore must be drilled thousands of feet into the earth to reach the hydrocarbon-bearing formations. Usually, but not always, the greater the depth of the well, the higher the natural “static” temperature of the formation.[0005]After drilling an openhole, the next step is referred to as “completing” the wellbore. A wellbore is sometimes complet...

AI Technical Summary

Problems solved by technology

This particulate material can be damaging to pumps and other oilfield equipment and operations.

The fracturing fluid is injected through the wellbore at such a high flow rate and under such high pressure that the rock of the subterranean formation that is subjected to the hydraulic treatment literally cracks apart or fractures under the strain.

However, once the high pressure is relieved by the escape of the fracturing fluid through the created fracture and out further into the subterranean formation, the fracture has a tendency to be squeezed closed by the natural pressures on the rock within the deep subterranean formation.

The fines have a tendency to plug small pore spaces in the formation and block the flow of oil.

Moreover, the fines are highly abrasive and can be very harmful to pumping equipment.

Crosslinks formed by zirconium, titanium, antimony, and aluminum compounds, however, are considered to be not reversible and are broken by other methods than controlling pH.

Unfortunately, another complicating factor also exists.

Once the polymer concentrates it is difficult to solubilize the polymer.

When the fracture closes, the permeability of the proppant bed may be damaged severely by the polymer filtercake.

Premature reduction of viscosity during the pumping of a fracturing treatment can jeopardize the treatment.

Inadequate reduction of fluid viscosity after pumping can also reduce production if the required conductivity is not obtained.

At very low temperatures enzymes are not as effective as rate of breakage of polymer is very slow and they are generally not recommended.

Acids, however, pose various difficulties for practical applications.

Acids are not used as a polysaccharide polymer breaker very often because of cost, poor break rate control, chemical compatibility difficulties, and corrosion of metal goods.

In particular, there are few methods available to break viscosifying polymers, especially xanthan polymers, at very low temperatures (below 120° F. / 49° C.) and they suffer from various problems.

For example, the use of hypochlorite poses corrosion concerns and may not provide sufficient delay of the break.

The use of sodium chlorite is limited to high-temperature applications and may react violently to cause a fire when organic compounds are used in the process.

Enzymes do not work well on xanthans.

However, we were unable to break a xanthan gel at very low temperature using the published recipe and the publication does not provide sufficient detail to allow the user to optimize the breaker recipe for a given set of conditions.

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