Ykk Corporation

William E Foxenberg

Hui Joyce Zhang

Balakrishnan Panamarathupalayam

David P Kippie

Robert L Horton

Changping Sui

Balkrishna Gadiyar

Charles Svoboda

Alhad Phatak

John W Powell

An insulating packer fluid including an oleaginous fluid and a styrenic thermoplastic block copolymer and methods of preparing the packer fluid are provided. Also provided are methods of using the insulating packer fluid that include pumping an insulating packer fluid into an annulus formed between two concentric strings of pipe extending into a wellbore.

High temperature viscosifier for insulating packer fluids

Insulating packer fluids containing colloidal silica inorganic additives may be used in methods that reduce convective currents in a packer fluid. In other aspects, packer fluids containing colloidal silica inorganic additives may be used in methods of insulating production wells and methods for stimulating production of hydrocarbons.

Colloidal silica and polymer system for insulating packer fluids

In a method of gravel packing a wellbore in a subterranean formation, the wellbore having a cased section and an uncased section, the method may include pumping into the wellbore a gravel pack composition having gravel and a carrier fluid, where the carrier fluid includes an oleaginous fluid and an inorganic solid aggregator material.

Methods of using oleaginous fluids for completion operations

A method of injection of a higher density fluid into the top of the annulus of a well while lower density fluid is withdrawn from the top of the annulus of the well, wherein the higher density fluid has a composition such that it will drop through the lower density fluid without dispersing therein, thus flowing into the deeper reaches of the annulus and not short circuiting through the top of the annulus to the point from which the lower density fluid is intended to be withdrawn. A method of injection of a higher density fluid into the top of the annulus of a well without simultaneously withdrawing a lower density fluid from the top of the annulus of the well, wherein the higher density fluid has a composition such that it will drop through the lower density fluid without dispersing therein, thus flowing into the deeper reaches of the annulus so that when the pressure induced in the annulus as a result of this injection is subsequently bled off, principally the lower density fluid will be that which is withdrawn.

Remediation treatment of sustained casing pressures (SCP) in wells with top down surface injection of fluids and additives

A method of treating a well including injecting a thermally stable, substantially water-free well-treating fluid into the well, wherein the well-treating fluid comprises a polymer, a glycol compound, and a salt is disclosed. In another embodiment, a thermally stable, substantially water-free well fluid including a polymer, a diol compound, and a salt is disclosed.

Thermally stable, substantially water-free well fluid

High density, thermally stable, brine-based well fluids and methods of using the same are disclosed. In one embodiment a well fluid including water and a salt, the salt including at least one formate salt, wherein the weight-to-volume ratio of the well fluid is within the range of at least 120% to about 400% is disclosed. In another embodiment, a well fluid including water, a viscosifying agent, and a salt, the salt including at least one formate salt, wherein the weight-to-volume ratio of the well fluid is within the range of at least 120% to about 400% is disclosed. A method of treating a well using a well fluid, wherein the well fluid includes water and a salt, the salt including at least one formate salt, wherein the weight-to-volume ratio of the well fluid is within the range of at least 120% to about 400% is also disclosed.

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Pearland, TX, United States of America

William E Foxenberg