Halliburton Energy Services, Inc.

Ryan G Ezell

Ryan Matthew Van Zanten

Jun Wu

B Raghava Reddy

James Randolph Lovorn

Emad Bakri

Douglas J Harrison

Jay K Turner

William Walter Shumway

David L Carbajal

Jun Jim Wu

Emad Barki

A method of servicing a wellbore in a subterranean formation comprising preparing a composition comprising a base fluid, a thixotropic viscosifier, a gellable composition and a bridging material, applying a shear force to the composition such that the composition viscosity decreases, introducing the composition into a lost circulation zone in the subterranean formation, wherein the lost circulation zone comprises cavities greater than about 200 microns in diameter, decreasing the shear force applied to the composition, and allowing the composition to set in the lost circulation zone. A method of servicing a wellbore in a subterranean formation comprising placing a first stream comprising a dilute solution of a metal acrylate into a lost circulation zone in the subterranean formation, placing a second stream comprising an activator into the lost circulation zone, and forming a lost circulation material upon contacting of the metal acrylate and the activator, wherein the lost circulation material forms in from about 0 to about 60 minutes.

Compositions and systems for combatting lost circulation and methods of using the same

A method of servicing a wellbore in a subterranean formation comprising placing a first stream comprising a dilute solution of a metal acrylate into a lost circulation zone in the subterranean formation; placing a second stream comprising an activator into the lost circulation zone; and forming a lost circulation material upon contacting of the metal acrylate and the activator, wherein the lost circulation material forms in from about 0 to about 60 minutes. A method of servicing a wellbore in a subterranean formation comprising placing a composition comprising a dilute solution of a cross-linkable material and an encapsulated activator into a lost circulation zone in the subterranean formation; and allowing the composition to set.

Compositions and systems for combatting lost circulation and methods

Methods and fluids are provided that include, but are not limited to, a drilling fluid comprising an aqueous base fluid and a fluid loss control additive that comprises at least one polymeric micro gel and a method comprising: providing an aqueous based treatment fluid comprising a fluid loss control additive that comprises at least one polymeric micro gel; placing the aqueous based treatment fluid in a subterranean formation via a well bore penetrating the subterranean formation; allowing the fluid loss control additive to become incorporated into a filter cake located on a surface within the subterranean formation; allowing the filter cake to be degraded; and producing hydrocarbons from the formation. Additional methods are also provided.

Methods of using fluid loss additives comprising micro gels

Treatment fluid compositions may comprise transient polymer networks for use in methods related to subterranean applications. In one aspect, a method may include providing a treatment fluid comprising an aqueous base fluid and a transient polymer network, and placing the treatment fluid in a subterranean formation. In another aspect, a subterranean treatment fluid may include an aqueous-base fluid and a transient polymer network.

Treatment fluids comprising transient polymer networks

Compositions and methods relating to treatment fluids that comprise entangled equilibrium polymer networks in subterranean applications. Such methods include providing a treatment fluid comprising at least one entangled equilibrium polymer network, and placing the treatment fluid in a subterranean formation. Other methods include providing a treatment fluid having a first viscosity comprising an aqueous base fluid and at least one entangled equilibrium polymer network; placing the treatment fluid in a subterranean formation; contacting the treatment fluid with a hydrocarbon; and allowing the viscosity of the treatment fluid to decrease to a second viscosity that is lower than the first viscosity.

Treatment fluids comprising entangled equilibrium polymer networks

Polymeric additives used with viscoelastic surfactants, fluids comprising such additives and viscoelastic surfactants, and associated methods of use, are provided. In one embodiment, the methods comprise: providing a treatment fluid that comprises an aqueous base fluid, a viscoelastic surfactant, and an amphiphilic polymer, the amphiphilic polymer comprising a hydrophobic component, and a hydrophilic component comprising at least 15 monomer units; and introducing the treatment fluid into at least a portion of a subterranean formation.

Polymeric additives for enhancement of treatment fluids comprising viscoelastic surfactants and methods of use

A method of servicing hydrocarbon production equipment comprising locating at least a portion of a hydrocarbon flow conduit experiencing a loss of functionality; creating a port to access an interior flow bore of the hydrocarbon flow conduit; installing at least one piece of equipment proximate the access port, wherein the equipment has access to the interior flow bore via the access port; and placing a servicing composition into the conduit via the access port, wherein the servicing composition prevents the loss of materials from the interior of the hydrocarbon flow conduit to the surrounding environment.

Wellbore servicing compositions and methods of making and using same

A subterranean treatment additive comprising a viscoelastic surfactant and an amphiphilic polymer. Wherein the amphiphilic polymer comprises a hydrophobic component, and a hydrophilic component, the hydrophilic component itself comprising at least 15 monomer units. The subterranean treatment additive may be used as part of a treatment fluid with an aqueous base fluid that may be a brine.

A method comprises providing a treatment fluid having a first viscosity comprising an aqueous base fluid; a viscoelastic surfactant; and a stimuli-responsive water-soluble polymer; introducing the treatment fluid into a subterranean formation; and allowing the treatment fluid viscosity to change to a second viscosity in response to a stimulus.

Stimuli-responsive high viscosity pill

A method of controlling pressure in a wellbore can include placing a barrier substance in the wellbore while a fluid is present in the wellbore, and flowing another fluid into the wellbore while the first fluid and the barrier substance are in the wellbore. The first and second fluids may have different densities. Another method can include circulating a fluid through a tubular string and an annulus formed between the tubular string and the wellbore, then partially withdrawing the tubular string from the wellbore, then placing a barrier substance in the wellbore, then partially withdrawing the tubular string from the wellbore and then flowing another fluid into the wellbore. A well system can include at least two fluids in a wellbore, the fluids having different densities, and a barrier substance separating the fluids.

Wellbore pressure control with segregated fluid columns

An inhibitive water-based polymer mud system and method for using the system in drilling and in stabilizing wellbores is disclosed for use in water sensitive formations as an alternative to oil-based muds. The system comprises a substantially non-ionic low molecular weight polyacrylamide in combination with a substantially non-ionic high molecular weight polyacrylamide, preferably long chain alcohol or an amine or silicate shale inhibitor, and poly anionic cellulose.

Growing community of inventors

Spring, TX, United States of America

Ryan G Ezell