Halliburton Energy Services, Inc.

Jason Maxey

Antonio Recio, Iii

HsinChen Chung

Omprakash Ramkhilavan Pal

Denise Nicole Benoit

Pratiksha Shivaji Meher

Gladys Rocio Montenegro-Galindo

Dale E Jamison

Ronald Glen Dusterhoft

Rahul Chandrakant Patil

Xiangnan Ye

Ubong Akpan Inyang

Travis Hope Larsen

Ryan Matthew Van Zanten

Narongsak Tonmukayakul

Sunita Sameer Kadam

Antonio Recio

Walter T Stephens

Amit Chandrakant Agrawal

Neil Joseph Modeland

Shoy Chittattukara George

Humberto Almeida Oliveira

V Ramireddy Devarapalli

Ramesh Uppuluri

Jeremy Blair Magness

Lu Zheng

Described herein is a low-temperature catalyst and method of use for causing an exothermic reaction in a low temperature environment. The mixture can include sodium nitrite, an ammonium-based compound, and an oxidizer 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 for exothermic reaction in a wellbore

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

Compositions and methods using subterranean treatment fluids comprising water-soluble polymers are provided. In some embodiments, the methods include: adding an anionic or amphoteric water-soluble polymer to a treatment fluid comprising an aqueous base fluid; adding a dewatering agent to the treatment fluid, wherein the dewatering agent comprises an aqueous phase, a solvent, a co-solvent, and one or more surfactants selected from the group consisting of: ethoxylated alcohol, a polyamine polyether, a resin alkoxylated oligomer, and any combination thereof; and introducing the treatment fluid into a well bore penetrating at least a portion of the subterranean formation.

Compositions and methods using subterranean treatment fluids comprising water-soluble polymers

Described herein are penetrating compositions that include ethoxylated C12-C16 alcohols, 2-ethyl hexanol, and isopropyl alcohol, and are injectable into a near-wellbore subterranean formation. The penetrating compositions may include water or brine. The penetrating compositions are free of ethylene glycol monobutyl ether (EGMBE) and nonylphenol ethoxylates (NPE). Also described are methods of using penetrating compositions that that include introducing a penetrating composition into a near-wellbore formation and reducing surface tension at an oil/water interface within the formation.

Penetrating compositions with reduced cloud point for acidizing applications

Methods disclosed improve the cluster efficiency during stimulation treatment, such as fracturing treatments. The methods incorporate any combination of the following: slurry rate ramp, proppant ramp and hold, and constant apparent viscosity during the stimulation treatment.

Proppant ramp-up for cluster efficiency

Application of polyaminated fatty acid-based oil compositions to additive particles to control dusting. A method reducing an amount of dust produced during transfer of additive particles in well operations may comprise providing treated additive particles comprising additive particles and a polyaminated fatty acid-based oil composition disposed on a surface of at least portion of the particles, wherein the polyaminated fatty acid-based oil composition comprises a polyaminated fatty acid and an organic solvent. The method may further comprise mixing components comprising the treated additive particles and a base fluid to provide a treatment fluid. The method may further comprise introducing the treatment fluid into a subterranean formation.

Using polyaminated fatty acid-based oil compositions for controlling dust from additive particles

Application of lecithin-based oil compositions to additive particles to control dusting. Without limitation, a method of reducing an amount of dust produced during transfer of additive particles in well operations may comprise providing treated additive particles comprising additive particles and a lecithin based oil composition disposed on a surface of at least portion of the particles. The lecithin -based oil composition may comprise a lecithin and an organic solvent. The method may further comprise mixing components comprising the treated additive particles and a base fluid to provide a treatment fluid. The method may further comprise introducing the treatment fluid into a subterranean formation.

Using lecithin-based oil compositions for controlling dust from additive particles

A method of treating a subterranean formation is disclosed. The method can include placing in the subterranean formation a crosslinked composition that includes proppant particles including polymer coatings thereon. The crosslinked composition includes inter-particle crosslinks between the polymer coatings of at least some of the proppant particles. The inter-particle crosslinks includes a crosslinker.

Crosslinked polymer-coated proppant

Systems and methods for controlling flow in downhole operations are described. Systems and methods may include a composition including a fracturing fluid base; one or more ionic compounds; a polymer; a crosslinking agent; and a pH modifier. A breaker may be provided in the composition. The composition may be provided to a formation to control flow, and syneresis may occur.

Controlling flow in downhole operations

A flow conditioning opening may be used to manipulate the flow of particulates in a particulate laden fluid in a downhole environment. The particulate flow may be manipulated towards or away from openings downstream of the flow conditioning opening. For example, a perforation cluster may include a flow conditioning opening extending from the wellbore into the subterranean formation that is aligned axially along the wellbore with and uphole of a perforation, wherein the flow conditioning opening has at least one of the following characteristics selected from the group consisting of: the flow conditioning opening having a smaller cross-sectional area at a wellbore face than the perforation, the flow conditioning opening having a smaller volume in the subterranean formation than the perforation, the flow conditioning opening having a smaller depth into the subterranean formation than the perforation, and any combination thereof.

Flow conditioning openings

Diverter compositions including an invert emulsion. A method of treating a subterranean formation. The method can include placing in a subterranean formation a diverter composition including an invert emulsion. The invert emulsion includes a continuous oil phase that includes at least one rheological modifier. The invert emulsion also includes an internal aqueous phase.

Diverter composition including rheologically-modified invert emulsion and method of use

Various embodiments disclosed relate to acidizing compositions including an ampholyte polymer. Various embodiments provide a method of treating a subterranean formation. The method can include placing in a subterranean formation an ampholyte polymer including an ethylene repeating unit including a &#x2014;C(O)NHgroup, an ethylene repeating unit including an &#x2014;S(O)ORgroup, and an ethylene repeating unit including an &#x2014;NRXgroup. At each occurrence, Rcan be independently selected from the group consisting of &#x2014;H and a counterion. At each occurrence, Rcan be independently substituted or unsubstituted (C-C)hydrocarbyl. At each occurrence, Xcan be independently a counterion.

Acidizing compositions including ampholyte polymers

Computer-implemented methods, software, and systems for determining a property of a wellbore fluid are disclosed. In some implementations, a computing system receives an image of a first sample of the wellbore fluid filling a conduit to a threshold volume of the conduit. The computing system determines a first time duration of the first sample of the wellbore fluid filling the conduit to the threshold volume of the conduit based on the image of the first sample. The computing system receives an image of a second sample of the wellbore fluid filling the conduit to the threshold volume of the conduit. The computing system determines a second time duration of the second sample of the wellbore fluid filling the conduit to the threshold volume of the conduit based on the image of the second sample. A property of the wellbore fluid is determined based on a difference between the first and second time durations.

Growing community of inventors

Spring, TX, United States of America

Jason Maxey