Halliburton Energy Services, Inc.

Alyssa Lynn Smith

Enrique Antonio Reyes

Aaron Michael Beuterbaugh

Christopher Lynn Smith

B Raghava Reddy

Benjamin Edward LaBlanc

Wirdansyah Lubis

Benjamin Edward Lablanc

Drew Henry Gaugler

A composition and method for using seawater as a treatment fluid is provided. The treatment fluid comprises N-(phosphonomethyl)iminodiacetic acid and seawater. The provided treatment fluid is stable and viscous, even at high temperatures and a high pH.

Composition and method for improved treatment fluid

Various embodiments disclosed relate to compositions for treatment of a subterranean formation, and methods and systems including the same. In various embodiments, the present invention provides a method of treating a subterranean formation that can include obtaining or providing a substantially solid composition. The substantially solid composition can include a hydrogen fluoride precursor salt and an amide hydrochloride salt. The method includes combining the substantially solid composition with a carrier fluid to form a mixture. The method includes placing the mixture in a subterranean formation downhole.

Substantially solid acidizing composition for treatment of subterranean formations

Certain metal surfaces are often unable to be effectively contacted with fluids containing hydrofluoric acid due to significant corrosion issues. Titanium and titanium alloy surfaces represent but one example. Corrosion inhibitor compositions comprising boric acid and an N-(phosphonoalkyl)iminodiacetic acid or any salt thereof can be used to suppress metal corrosion, including that taking place on titanium and titanium alloy surfaces. Methods for suppressing corrosion of a metal surface can comprise: contacting a metal surface with a corrosive environment, the metal surface comprising titanium or a titanium alloy and the corrosive environment comprising hydrofluoric acid; introducing a corrosion inhibitor composition to the corrosive environment, the corrosion inhibitor composition comprising boric acid and an N-(phosphonoalkyl)iminodiacetic acid or any salt thereof; contacting the metal surface with the corrosion inhibitor composition; and allowing the corrosion inhibitor composition to suppress corrosion of the metal surface by the corrosive environment.

Methods and systems for suppressing corrosion of sensitive metal surfaces

Methods for reducing viscosifying tendencies of crude oil in subterranean formations using solid acid chelating agents are described. The methods include combining a solid acid chelating agent and an aqueous acid solution to form a treatment fluid, and introducing the treatment fluid into the subterranean formation. The solid acid chelating agent includes at least one aminopolycarboxylic acid functional group and at least one phosphonic acid functional group.

Non-reducing stabilization complexant for acidizing compositions and associated methods

When used outside the pH range at which metal ion complexation normally occurs, aminopolycarboxylic acids can moderate the reaction rate of acids with carbonate minerals. Methods for treating a subterranean formation can comprise: providing a treatment fluid comprising an aqueous carrier fluid, an acid, and a chelating agent comprising an aminopolycarboxylic acid, the treatment fluid having a pH below that at which the carboxylic acid groups of the chelating agent are substantially protonated and the chelating agent is ineffective for complexing a metal ion; introducing the treatment fluid into a subterranean formation comprising a carbonate mineral; reacting the acid with the carbonate mineral, such that the acid at least partially spends and the pH of the treatment fluid rises; and once the pH of the treatment fluid rises above a pKvalue for one or more of the carboxylic acid groups, complexing a metal ion with the chelating agent.

Methods and systems for acidizing subterranean formations with treatment fluids containing dual-functioning chelating agents

Particles that comprise calcium methylglycine diacetic acid salt ('Ca-MGDA salt') may be useful for fluid diversion in subterranean operations. In some instances, the particles may be formed in the subterranean formation. For example, a method may involve introducing a treatment fluid into a wellbore penetrating a subterranean formation, wherein the treatment fluid comprises an aqueous base fluid, MGDA or salt thereof, and an acid in an amount of about 3% or greater by weight of the aqueous base fluid; acidizing a portion of the subterranean formation comprising calcium carbonate resulting in a concentration of calcium in the treatment fluid that exceeds about 50,000 ppm; and precipitating a plurality of particles that comprise a Ca-MGDA salt in the portion of the subterranean formation, thereby reducing fluid flow therethrough. In some instances, the particles that comprise Ca-MGDA salt may be included in a treatment fluid before introduction into the subterranean formation.

Calcium methylglycine diacetic acid salt particles and subterranean operations relating thereto

Treatment fluids and methods include a method that includes the steps of providing or preparing a foamed chelating agent treatment fluid that includes: an aminopolycarboxylic acid chelating agent, an aqueous base fluid, a gas, and a foaming agent, and lacing the foamed chelating agent treatment fluid in a subterranean formation penetrated by a well bore. The aminopolycarboxylic acid chelating agent foamed fluids may also be used in equipment clean-out operations.

Foamed chelating agent treatment fluids for use in subterranean matrix stimulations and subterranean and surface cleanout operations

Geothermal wells frequently form deposits of geothermal scale that can detrimentally affect subterranean operations. These deposits can be very difficult to remove from a surface. Conventional procedures for addressing geothermal scale often provide inadequate scale removal, in addition to creating a number of other issues. Methods for removing geothermal scale from a wellbore can comprise: introducing a descaling agent comprising an N-(phosphonoalkyl)iminodiacetic acid or any salt thereof into a wellbore of a geothermal well having geothermal scale present therein; contacting the geothermal scale with the descaling agent; and removing at least a portion of the geothermal scale from the geothermal well using the descaling agent.

Methods and systems for removing geothermal scale

Methods of acidizing subterranean formations using solid acids are described. The methods include providing a treatment fluid containing a solid acid chelating agent and introducing the treatment fluid into the subterranean formation. The solid acid chelating agent includes at least one aminopolycarboxylic acid functional group and at least one phosphonic acid functional group. The treatment fluid is substantially free of an additional acid or acid-generating compound.

Solid acids for acidizing subterranean formations

The presence of iron in a subterranean formation, particularly ferric iron, can be problematic during an acidizing operation due to sludge formation that can occur. Methods for treating a subterranean formation in the presence of iron can comprise: providing a treatment fluid comprising an acid and an iron stabilization agent comprising a phosphinated carboxylic acid polymer, the treatment fluid having a pH of about 3 or below and the phosphinated carboxylic acid polymer being soluble in the treatment fluid; introducing the treatment fluid into a subterranean formation; and interacting the phosphinated carboxylic acid polymer with ferric iron in the subterranean formation.

Methods and systems for iron control using a phosphinated carboxylic acid polymer

A method of servicing a wellbore in a subterranean formation comprising preparing a wellbore servicing fluid comprising an amino polyether multicarboxylic acid chelating agent and/or an amino polyether multicarboxylic acid chelating agent precursor, and an aqueous base fluid, and contacting the wellbore servicing fluid with scale deposits on a surface in the wellbore and/or subterranean formation. A method of servicing a wellbore in a subterranean formation comprising preparing a wellbore servicing fluid comprising an amino polyether multicarboxylic chelating agent precursor and an aqueous base fluid, and contacting the wellbore servicing fluid with scale deposits on a surface in the wellbore and/or subterranean formation. A scale-removing wellbore servicing fluid comprising an amino polyether multicarboxylic acid chelating agent and/or an amino polyether multicarboxylic acid chelating agent precursor, and an aqueous base fluid.

Wellbore servicing compositions and methods of making and using same

Acidizing operations in subterranean formations that contain both a siliceous material and a source of calcium ions can often be problematic due to the generation of calcium-containing precipitates, particularly calcium fluoride. Methods for treating a subterranean formation can comprise: providing a treatment fluid having a pH ranging between about 1 and about 4.5 and comprising a chelating agent, hydrofluoric acid or a hydrofluoric acid-generating compound, and a compound having two or more quaternized amine groups; introducing the treatment fluid into a subterranean formation containing a siliceous material and a source of calcium ions; dissolving at least a portion of the siliceous material in the subterranean formation with the hydrofluoric acid or the hydrofluoric acid-generating compound; and complexing at least a portion of the calcium ions in the subterranean formation with the chelating agent.

Complexation of calcium ions in the presence of quaternized amine compounds while acidizing a subterranean formation

Carbon dioxide generation in a subterranean formation can be problematic for a number of reasons. Accordingly, it can be desirable to sequester at least a portion of the carbon dioxide that may be present in a subterranean formation, thereby decreasing a quantity of free carbon dioxide. Methods for sequestering carbon dioxide can comprise: providing a CO-sequestering polymer, the CO-sequestering polymer sequestering carbon dioxide more readily than it does nitrogen; introducing the CO-sequestering polymer into a subterranean formation that contains carbon dioxide; and interacting the CO-sequestering polymer with the carbon dioxide in the subterranean formation, so as to decrease a quantity of free carbon dioxide that is present in the subterranean formation.

Methods and systems for sequestering carbon dioxide in a subterranean formation

Acidizing fluids may be formulated to minimize the detrimental effects of precipitation during an acidizing operation by promoting production of precipitates from a subterranean formation. Methods for acidizing a subterranean formation can comprise: providing an acidizing fluid comprising a stabilized microemulsion carrier fluid, a chelating agent, and an acid source; introducing the acidizing fluid into a subterranean formation; at least partially dissolving a surface in the subterranean formation with the acidizing fluid, thereby forming a spent fluid; and producing the spent fluid from the subterranean formation.

Methods for acidizing a subterranean formation using a stabilized microemulsion carrier fluid

In situ generation of hydrogen fluoride or other reactive fluoride species can sometimes be beneficial during an acidizing operation, particularly when it is desired to limit the presence of a carrier fluid that may be present. Methods for acidizing a subterranean formation can comprise: providing a treatment fluid comprising a non-HF fluoride compound, the non-HF fluoride compound being a gas at standard temperature and pressure and that is free of boron; introducing the treatment fluid into a subterranean formation; transforming the non-HF fluoride compound into a reactive fluoride species; and etching a surface in the subterranean formation with the reactive fluoride species, the surface comprising a siliceous material.

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Humble, TX, United States of America

Alyssa Lynn Smith