Halliburton Energy Services, Inc.

Sunita Sameer Kadam

Rahul Chandrakant Patil

Vaishali Mishra

V Ramireddy Devarapalli

Rajendra Arunkumar Kalgaonkar

Alexandra Clare Morrison

Sudarshana Mukherjee

Mahesh Vijay Biyani

Mohamed Abdel Salam

Bhau Anantha Kuchik

Philip D Nguyen

Larry Steven Eoff

Krishna M Ravi

Jay Paul Deville

William Walter Shumway

Hui Zhou

Sandip Prabhakar Patil

Rajender Salla

Siva Rama Krishna Jandhyala

Ganesh Shriniwas Pangu

Ravikant S Belakshe

Jason Maxey

Sherif Eldin

Amit Chandrakant Agrawal

Nivika Rajendra Gupta

Sandeep Vasant Chavan

Sharad Bhimrao Gotmukle

Pratiksha Shivaji Meher

Vilas Ramtenki

Jag Pravesh

Siddharth Roy

Wiliam W Shumway

Shreyasi Goswami

Sohini Bose

Rajashree Lad

Jason Adam Denny

A reservoir fluid can be produced from a subterranean formation. The reservoir fluid can include water and hydrocarbons such as oil. It is oftentimes desirable to limit the amount of water that is produced, so a higher ratio of hydrocarbons can be produced. Portions of the subterranean formation can have an initial permeability to water. A relative permeability modifier (RPM) package including a surfactant and a polymer can be used in these portions to restrict or prevent water from being produced. The relative permeability modifier package can increase the hydrophobicity of the portion that allows the hydrocarbons to flow through while substantially limiting the amount of water. The relative permeability modifier can coat the surfaces of substances in the formation whereby the permeability to an aqueous fluid is reduced from the initial permeability. The formation can be a high-temperature formation of 230° F. (110.0° C.) or greater.

Relative permeability modifier package for produced fluids from a subterranean formation

Described herein is a combination of a catalyst and an activator and method of use for causing an exothermic reaction in a low temperature environment. The mixture can include sodium nitrite, an ammonium-based compound, a catalyst that comprises an oxidizer, and an activator and can be injected into a fluid flow path. The fluid flow path can be a pipeline, a flowline, a wellbore, or a subterranean formation. The mixture can cause an exothermic reaction in the fluid flow path and remove, using the exothermic reaction, a damaging material from the fluid flow path.

Catalyst and activator for exothermic reaction

A variety of methods and compositions are disclosed, including, in one example, a method that includes introducing a drill-in fluid into a production zone of a subterranean formation, where the drill-in fluid includes water, a hydrophobically modified starch, a dual oil and water soluble surfactant, and a bridging agent, extending a borehole through the production zone, and forming a filter cake in the production zone where the filter cake includes a plurality of oleophilic channels is formed within the filter cake.

Active filter cake component for reservoir drill-in fluids to eliminate acid treatment

A breaker composition comprising: (i) an acid precursor, (ii) a delaying agent and (iii) an aqueous fluid wherein the breaker composition has an effective operating temperature range of from about 25° C. to about 180° C. A wellbore servicing system comprising (a) an aqueous-based drilling fluid, wherein the aqueous-based drilling fluid forms water-wet solids in the wellbore; and (b) a breaker composition comprising (i) an acid precursor, (ii) a delaying agent and (iii) an aqueous fluid. A method of dissolving a filtercake comprising contacting the filtercake with a breaker solution comprising (i) an acid precursor, (ii) a delaying agent and (iii) an aqueous fluid wherein the filtercake comprises calcium carbonate.

Filter cake removal compositions and methods of making and using same

A breaker composition comprising (i) an acid precursor, (ii) an accelerating agent wherein the accelerating agent comprises a Lewis acid and (iii) an aqueous fluid wherein the effective operating temperature of the breaker composition ranges from about 15° C. to about 120° C. A wellbore servicing system comprising (a) an aqueous-based drilling fluid, wherein the aqueous-based drilling fluid forms water-wet solids in the wellbore; and (b) a breaker composition comprising (i) an acid, (ii) an accelerating agent and (iii) an aqueous fluid. A method of dissolving a filtercake comprising contacting the filtercake with a breaker solution comprising (i) an acid precursor, (ii) an accelerating agent and (iii) an aqueous fluid wherein the filtercake comprises calcium carbonate.

A treatment fluid can include a base fluid and a lost-circulation package. The lost-circulation package can include plurality of particles of a first, second, and third lost-circulation material. The plurality of particles can be cellulose, sized calcium carbonate, and fibers. The particle size distribution of the plurality of particles can be selected such that the particles enter permeable areas of a subterranean formation to help prevent loss of the base fluid into the formation and allow most of the particles to pass through the screen of a shale shaker. The plurality of particles can have a particle size distribution of a d10 value in the range of 30 to 55 microns, a d50 value in the range of 60 to 100 microns, and a d90 value in the range of 130 to 190 microns. The treatment fluid can be used in an oil and gas operation.

Lost circulation material package with tailored particle size distribution

A method of drilling a wellbore penetrating a subterranean formation, the method includes: during drilling operations, circulating in the wellbore a first aqueous drilling fluid composition including a modified starch and a calcium carbonate wherein the calcium carbonate has a first predetermined particle size; during the circulating, measuring one or more parameters to create a set of measured parameters; and during the circulating, responsive to one or more parameters of the set of measured parameters, changing the calcium carbonate with another calcium carbonate of a different particle size to obtain a second aqueous drilling fluid composition, wherein the first and second predetermined particle sizes are, independently, a dparticle size of about 1.0 &#x3bc;m to about 150 &#x3bc;m.

Changing calcium carbonate particle size with starch for reservoir fluids

Methods for treating fluids used in the production and/or transport of petroleum products and natural gas, and methods for the removal of acidic gases encountered in fluids used and encountered in such operations are provided. In one embodiment, the methods include introducing a treatment fluid including a polymeric swellable acid scavenger that includes at least one polymeric composition into a wellbore penetrating at least a portion of a subterranean formation in which an acidic gas, an acid-containing fluid, or both, are present.

Polymeric swellable scavengers for acidic gases

Provided is a method for mitigating a lost circulation zone. The method may include providing a lost circulation treatment composition that may include an acid responsive polymer that may include at least one monomer, at least one comonomer, and at least one crosslinker; a carbonate-based solvent; and a carrier fluid that may include water. The method may also include introducing the lost circulation treatment composition into a wellbore within a subterranean formation, wherein the subterranean formation may include the lost circulation zone; placing the lost circulation treatment composition into the lost circulation zone, hydrolyzing the carbonate-based solvent to generate carbon dioxide, and causing the swelling (change of shape) of acid responsive polymer to mitigate the losses.

Stimuli responsive polymers for lost circulation applications

Described herein are fluids used to inhibit swelling of clay or shale formations, where the fluids include a drilling fluid and a clay stabilizer that include a potassium salt with a plurality of cations and are injectable into a wellbore.

Potassium salt treatment fluids for clay stabilization

Methods and systems are directed to the uniform distribution of a fluid through an annulus between a pipe and a wellbore wall, primarily when there is a preferential flow in one side of the annulus relative to another side of the annulus. Generally, the methods and systems involve introducing a first agent into the annulus, wherein the first agent is configured to cause swelling of a cladding on the exterior of the section of the pipe. The swelling reduces flow in the annulus on the side of the pipe with preferential flow so as to reduce the preferential flow on that side of the pipe.

Method to attain full annular coverage during cementing or mud circulation

Methods for producing a swellable packer in a downhole environment are provided. A method includes introducing a treatment fluid containing a polymeric composition into a wellbore within the downhole environment and exposing the polymeric composition to an acid to produce a swollen polymeric material within the downhole environment. The polymeric composition contains a reaction product of at least one or more monomers, one or more comonomers, and one or more crosslinkers. The acid can be in situ formed from an acid precursor introduced into the downhole environment.

Swellable packers and methods for activating swellable packers in a downhole environment

Methods of introducing a treatment fluid into a subterranean formation having a filtercake deposited thereon, wherein the treatment fluid comprises a base fluid and an inclusion complex comprising a cyclodextrin compound and an acid precursor ester, and wherein the cyclodextrin compound delays hydrolysis of the acid precursor ester; contacting the treatment fluid with the filtercake; and hydrolyzing the acid precursor ester, thereby removing at least a portion of the filtercake.

Treatment fluids for reducing subterranean formation damage

Compositions, methods, and systems for mitigating annular pressure buildup in a wellbore. A method comprises introducing a spacer fluid into an annulus of the wellbore, wherein the spacer fluid comprises an aqueous base fluid, an acid swellable polymer, and a hydrolysable ester. The method further comprises allowing or causing to allow at least a portion of the spacer fluid to remain in the annulus; and allowing or causing to allow a temperature to increase in the annulus to the temperature sufficient to hydrolyze the hydrolysable ester; wherein hydrolysis of the hydrolysable ester produces an acid; wherein the acid reacts with the acid swellable polymer to produce a salt; and wherein the produced salt has a thermal expansion coefficient less than that of the aqueous base fluid.

Annular pressure buildup mitigation using acid swellable polymer system

Various embodiments disclosed relate to proppant including a swellable coating thereon for treatment of subterranean formations. In various embodiments, the present invention provides a method of treating a subterranean formation. The method includes placing in the subterranean formation a proppant including a coating thereon. The coating is swellable with aqueous medium in response to a trigger including acidic pH, CO, HS, or a combination thereof.

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Pune, India

Sunita Sameer Kadam