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High temperature stabilizer for well treatment fluids and methods of using same

a technology of stabilizer and well treatment fluid, which is applied in the direction of fluid removal, wellbore/well accessories, chemistry apparatus and processes, etc., can solve the problems of reducing the viscosity of the fluid, and exceeding the maximum operating limits of conventional well treatment fluid, etc., to achieve the effect of increasing the viscosity and facilitating hydration

Inactive Publication Date: 2012-01-19
BAKER HUGHES INC
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  • Summary
  • Abstract
  • Description
  • Claims
  • Application Information

AI Technical Summary

Benefits of technology

[0009]A method for treating a well penetrating a subterranean formation having a temperature of up to about 500° F. (260° C.) is also provided as another embodiment of the present invention. In this embodiment, the method includes contacting at least a portion of the subterranean formation with a high temperature well treatment fluid. In embodiments of the present invention, the high temperature well treatment fluid includes a polymeric gel and an electron donating compound comprising phenothiazine that prevents thermal degradation of the polymeric gel at temperatures of up to about 500° F. (260° C.). In this embodiment, the high temperature well treatment fluid can be a hydraulic fracturing fluid, a drilling mud, a completion fluid, or a workover fluid.
[0011]Additional additives can be added to the high temperature well treatment fluids of the present invention. Such additives can include additional monomers that can be copolymerized with the polymeric gels of the high temperature well treatment fluids, secondary stabilizers to help the high temperature well treatment fluids perform for extended periods of time, crosslinking agents to help increase the viscosity of the high temperature well treatment fluids, breakers to help break down the high temperature well treatment fluids, surfactants that help with hydration of the high temperature well treatment fluids, and the like. Other suitable additives that are useful in high temperature well treatment fluids, such as proppant, will be apparent to those of skill in the art and are to be considered within the scope of the present invention.

Problems solved by technology

As operators continue to drill significantly deeper to access hydrocarbon bearing formations, the conditions in which well treatment fluids must operate often exceeds the maximum operational limits of conventional well treatment fluids.
The degradation generally gets worse as the temperatures continue to increase.
Most degradation results in the cleavage of the polymer chains, which simultaneously reduces the fluid's viscosity.
Unfortunately, many subterranean formations have temperatures well above this level.

Method used

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  • High temperature stabilizer for well treatment fluids and methods of using same
  • High temperature stabilizer for well treatment fluids and methods of using same
  • High temperature stabilizer for well treatment fluids and methods of using same

Examples

Experimental program
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Effect test

example 1

[0043]The electron donating compound comprising phenothiazine was mixed at 360° F. (182.2° C.) with two guar-based fracturing fluids that are commercially available under the commercial names Medallion Frac HT® and Vistar® from BJ Services Company. In addition order, tap water, 10 wt. % methanol, 12.5 gpt of the (slurried polymer XLFC-3 or VSP-1 by BJ Services Company respectively for Medallion Frac HT® and Vistar®) 1 gpt Claytreat-3C clay stabilizer (CT-3C) by BJ Services Company, 3 gpt stabilizer (GS-1L) by BJ Services Company, 0.2 gpt crosslink delay agent (XLD-1) by BJ Services Company, and 1.4 gpt zirconate-based crosslinker (XLW-14) by BJ Services Company were mixed with 50 ppt of the fracturing fluid to produce the samples. The pH of the Medallion Frac HT® system was about 10 and the pH of the Vistar® system was about 10.25. The concentration of the electron donating compound comprising phenothiazine was 120 ppm in the fracturing fluid, i.e., 3 gpt 9.7 wt. % in dipropylene gl...

example 2

[0044]Three samples were prepared in this example. The first sample was the control sample. In the second and third samples, the electron donating compound stabilizer comprising phenothiazine was mixed at varying amounts at 400° F. (204.4° C.) with 40 ppt high molecular weight polymer-based fracturing fluid comprising a copolymer derived from acrylamide. A suitable copolymer that was used in this example is commercially available as Allessan® AG 5028P from Allessa Chemie. The pH of the samples prepared in this example was about 5. In addition order, tap water, 10 wt. % methanol, 19.1 gpt of the polymer emulsion, 1 gpt Claytreat-3C clay stabilizer (CT-3C) by BJ Services Company, 3 gpt stabilizer (GS-1L) by BJ Services Company, 2.0 gpt zirconate-based crosslinker (XLW-65) by BJ Services Company and 2 gpt low pH buffer (BF-65L) by BJ Services Company were mixed to produce the samples. The high molecular weight polymer-based fracturing fluid was made in accordance with co-pending U.S. p...

example 3

[0047]Five samples were prepared in this example. The first top sample was the control sample at 400° F. (204° C.). In the remaining samples, the electron donating compound stabilizer comprising phenothiazine was mixed at varying amounts at 400° F. (204.4° C.) with 40 ppt or 50 ppt high molecular weight polymer-based fracturing fluid comprising a copolymer derived from acrylamide, as indicated in Table 1. A suitable copolymer that was used in this example is commercially available as Allessan® AG 5028P from Allessa Chemie. The components, addition order, and conditions in this example are as follows:

TABLE 1Sam-Sam-Sam-Sam-Sam-Component / Conditionple 1ple 2ple 3ple 4ple 5Copolymer (AG 5028P),4040404050pptGel stabilizer (GS-1L),33221.5gptBuffer, gpt22332Crosslinking agent22222(XLW-65), gptStabilizer, gpt—2444Temperature, ° F. (° C.)400400400425450

The samples were allowed to hydrate for 30 minutes. The pH of the samples prepared in this example was about 5. The high molecular weight pol...

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Abstract

A method of fracturing a subterranean formation by introducing into the formation a high temperature well treatment fluid containing a polymeric gel and an electron donating compound comprising phenothiazine or a phenothiazine derivative. The high temperature well treatment fluid may further contain a crosslinking agent or the polymeric gel may be crosslinked. The electron donating compound performs as a stabilizer in the treatment of wells having a subterranean formation temperature of up to about 500° F. (260° C.).

Description

[0001]This application is a divisional application of U.S. patent application Ser. No. 12 / 020,755, filed on Jan. 28, 2008.BACKGROUND OF THE INVENTION[0002]1. Field of the Invention[0003]The present invention relates to the use of polymeric compounds as thermal decomposition prevention additives for well treatment fluids.[0004]2. Description of the Related Art[0005]Well treatment fluids are useful in hydrocarbon completion operations in various functions, such as being proppant carriers in fracturing processes or as being fluid loss control agents in well completion and workover operations. Well treatment fluids often contain gels that are formed from polymers mixed with water.[0006]As operators continue to drill significantly deeper to access hydrocarbon bearing formations, the conditions in which well treatment fluids must operate often exceeds the maximum operational limits of conventional well treatment fluids. For example, as the drilling depths continue to increase, so do the f...

Claims

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Application Information

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Patent Type & Authority Applications(United States)
IPC IPC(8): E21B43/26
CPCC09K8/12C09K8/685C09K8/90C09K8/882C09K8/887C09K8/86
Inventor CARMAN, PAUL S.
Owner BAKER HUGHES INC
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