Halliburton Energy Services, Inc.

Championx USA Inc.

Narongsak Tonmukayakul

Yuntao Thomas Hu

Xiangnan Ye

HsinChen Chung

Rajesh Kumar Saini

Jason E Bryant

Pinmanee Boontheung

B Raghava Reddy

Enrique Antonio Reyes

Pious V Kurian

Michael A McCabe

Kin-Tai Chang

Kevin W Frederick

Randy J Loeffler

Joseph Paul Street

Jeff F Morris

Vyacheslav Boyraskikh

Roger Lynn Schultz

Thomas Donovan Welton

Feng Liang

Robert Lee Pipkin

Shih-Ruey Tom Chen

Daniel Robert Dreyer

James William Ogle

Ian D Robb

Lewis R Norman

Phillip C Harris

Benjamin John Iverson

Jeffrey M Morris

Jason Maxey

Keith Douglas Pewitt

Pandurang Manohar Kulkarni

Malcolm Talbot

Harvey Fitzpatrick

Robert Prudhomme

Sojwal Manoorkar

Hsinchen Chung

Rocky M Fitzgerald

Described are methods and compositions for treating a subterranean formation. The method comprising introducing into the subterranean formation via a well-bore a diverter composition, the diverter composition comprising a combination of at least one deformable particle and at least one non-deformable particle; and allowing the diverter composition to block the flow of at least a portion of a treatment fluid from a first location within the well-bore to a second location.

Fluid diversion composition in well stimulation

Ampholyte polymeric compound that comprises at least one nonionic monomer, at least one sulfonic acid-containing monomer, and at least one cationic monomer may be useful in viscosifying treatment fluids for use in subterranean operations at a concentration of about 0.5 v/v % to about 30 v/v % of the treatment fluid. Such operations may involve introducing the treatment fluid into a wellbore penetrating a subterranean formation optionally at a pressure sufficient to create or extend at least one fracture in the subterranean formation.

Ampholyte polymeric compounds in subterranean applications

Various embodiments disclosed relate to a composition including a crosslinkable ampholyte polymer or a crosslinked product of the same, methods of making and using the composition, and systems including the composition. In various embodiments, the present invention provides a method of treating a subterranean formation. The method can include obtaining or providing a composition including a crosslinkable ampholyte polymer. The crosslinkable ampholyte polymer can include an ethylene repeating unit including a &#x2014;C(O)NHgroup, an ethylene repeating unit including a &#x2014;S(O)ORgroup, and an ethylene repeating unit comprising 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. The composition can also include at least one crosslinker. The method can include placing the composition in a subterranean formation.

Ampholyte polymers and methods of treating subterranean formations with the same

Ampholyte polymeric compounds that comprise at least one nonionic monomer, at least one sulfonic acid-containing monomer, and at least one cationic monomer may be useful as friction reducing agents in treatment fluids for use in subterranean operations at a concentration of about 0.001 v/v % to about 0.5 v/v % of the treatment fluid. Such operations may involve introducing the treatment fluid into a wellbore penetrating a subterranean formation optionally at a rate and/or a pressure sufficient to create or extend at least one fracture in the subterranean formation.

Biomimetic adhesive compositions can be used in various aspects of subterranean treatment operations. Methods for treating a subterranean formation can comprise: providing an adhesive composition that comprises a first polymer comprising a plurality of monomers that comprise a phenolic moiety, a biopolymer that is crosslinkable with the first polymer, a crosslinking agent, and an oxidizing agent; introducing the adhesive composition into a subterranean formation; and forming a coacervate-bound surface in the subterranean formation by crosslinking the first polymer.

Biomimetic adhesive compositions comprising a phenolic polymer and methods for use thereof

A method of servicing a wellbore comprising placing a wellbore servicing fluid comprising a modified friction reducer into the wellbore. A modified friction reducer comprising a degradable polymer having functional degradable moieties, a polymer having a molecular weight of from about 5M to about 30M, a polymer having a PDI of from about 1.0 to about 2.5, a weakly crosslinked polymer, or combinations thereof.

Methods to prevent formation damage from friction reducers

Determining flow through a fracture junction in a complex fracture network. A flow of a fracturing fluid through a fracture junction of a complex fracture network is modeled using a fluid flow model that models flow based, in part, on mass balance and momentum balance. The fracture junction includes a first outlet to flow a first portion of the fracturing fluid and a second outlet to flow a second portion of the fracturing fluid. A ratio of a first volumetric flow rate of the first portion and a second volumetric flow rate of the second portion, and the pressure drop across the junction are determined in response to modeling the flow of the fracturing fluid through the fracture junction according to the fluid flow model. The determined ratio of flow rates and/or the determined pressure drop is provided.

Determining flow through a fracture junction in a complex fracture network

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.

Determining wellbore fluid properties

A method of servicing a wellbore comprising contacting a wellbore servicing composition with a rheology modifying additive wherein the rheology modifying additive comprises a gum and a polymeric material. A method of cementing in a subterranean formation comprising providing a sealant composition comprising cement, water, and a rheology modifying additive wherein the rheology modifying additive comprises a gum and an anionic polymer, placing the composition in the subterranean formation, and allowing the cement composition to set therein.

Compositions for modifying rheological properties of cement systems

Methods of decreasing the viscosity of a treatment fluid through contact with a cyclodextrin modifier. Such methods include providing a cyclodextrin modifier; providing a treatment fluid that comprises a base fluid and a viscosifying agent wherein the viscosifying agent is selected from the group consisting of a hydrophobically modified polymer, a viscoelastic surfactant, a phosphonate surfactant, or a combination thereof; and, introducing the cyclodextrin modifier and the treatment fluid into a well bore penetrating a subterranean formation wherein the viscosity of the treatment fluid is decreased due to the combination of the hydrophobically modified polymer and the cyclodextrin modifier.

Methods and compositions for altering the viscosity of treatment fluids used in subterranean operations

A method of determining one or more minimum rheological properties of a particle laden fluid is disclosed. The method includes determining one or more rheological properties of the fluid at a first shear rate, determining the settling velocity of the particles at the first shear rate, and obtaining a transport index for the fluid, the transport index indicating a relationship between the settling velocity and the one or more rheological properties.

Method for estimating proppant transport and suspendability of viscoelastic liquids

Methods are provided that include a method comprising: providing an emulsified treatment fluid comprising an oleaginous phase, an aqueous phase, a consolidating agent, and an emulsifying agent that comprises at least one convertible surfactant described by a one of the disclosed formulae, and placing the subterranean treatment fluid in a subterranean formation.

Consolidating emulsions comprising convertible surfactant compositions and methods related thereto

An embodiment of the present invention includes a method comprising introducing a cyclodextrin modifier into a well bore penetrating a subterranean formation. Another embodiment of the present invention includes a method of reducing viscosity of a treatment fluid comprising contacting a treatment fluid comprising a base fluid and a viscosifying agent with at least a cyclodextrin modifier wherein the cyclodextrin modifier interacts with the viscosifying agent to reduce viscosity of the treatment fluid. Another embodiment of the present invention includes a method of increasing viscosity of an aqueous fluid comprising contacting at least a hydrophobically modified polymer and a cyclodextrin modifier in the presence of at least the aqueous fluid, wherein the cyclodextrin modifier interacts with the hydrophobically modified polymer to viscosify the aqueous fluid. Another embodiment of the present invention includes a subterranean treatment fluid comprising a base fluid and a cyclodextrin modifier.

Growing community of inventors

Duncan, OK, United States of America

Narongsak Tonmukayakul