Paul M Mcelfresh, Age 7814327 Prosper Ridge Dr, Cypress, TX 77429

6805198, Oct 19, 2004

Aug 19, 2002

10/223118

Tianping Huang - Spring TX
Paul M. McElfresh - Spring TX
Allen D. Gabrysch - Houston TX

Baker Hughes Incorporated - Houston TX

G21B 4327

166307, 166304

Dicarboxylic acids are useful in acidizing subterranean formations to improve their permeability, particularly at elevated temperature, e. g. between about 200Â F. (92Â C. ) and about 400Â F. (204Â C. ). Particularly suitable dicarboxylic acids include, but are not necessarily limited to, succinic acid, glutaric acid, adipic acid, and mixtures thereof.

6994166, Feb 7, 2006

Jun 24, 2003

10/602230

Tianping Huang - Spring TX, US
Paul M. McElfresh - Spring TX, US

Baker Hughes Incorporated - Houston TX

E21B 43/27
E21B 33/138

166282, 166294, 166300, 507260, 507265, 507933

It has been discovered that solid, particulate dicarboxylic acids are useful as diverting agents in methods for acidizing subterranean formations to improve the uniformity of the acid treatments (acid displacement) by diverting acid to intervals of relatively less permeability. Particularly suitable solid, particulate dicarboxylic acids include, but are not necessarily limited to, those insoluble in both aqueous and hydrocarbon liquids, but which are soluble in mutual solvents or alcohol blends. These acids may have melting points of from about 180 to about 300 F. (about 82 to about 149 C. ), formula molecular weights of from 146 to 400, and mesh sizes of from about 20 mesh to about 400 mesh (about 841 to about 38 microns). Particular dicarboxylic acids that fit this description include, but are not necessarily limited to, dodecanedioic acid, undecanedioic acid, decanedioic acid, azelaic acid, suberic acid, and mixtures thereof.

7216709, May 15, 2007

Oct 28, 2004

10/975730

Paul M. McElfresh - Spring TX, US
Chad F. Williams - Kingwood TX, US

Akzo Nobel N.V. - Arnhem

E21B 43/02
E21B 21/00

166300, 166283, 1663051, 1663082, 1663083, 172 72, 507245, 507265

The present invention generally relates to a method for treating a subterranean formation with an aqueous viscoelastic treating fluid that an aqueous base fluid and one or more non-ionic amido amine oxide surfactant gelling agents. The treatment method comprises injecting the aqueous viscoelastic surfactant treating fluid through a wellbore and into the subterranean formation under conditions effective to control fluid loss, and breaking the gel of the aqueous viscoelastic treating fluid subsequent to treating said formation.

7461699, Dec 9, 2008

Oct 19, 2004

10/968534

Bennett M. Richard - Kingwood TX, US
Paul McElfresh - Spring TX, US
Chad Williams - Kingwood TX, US

Baker Hughes Incorporated - Houston TX

E21B 29/02
E21B 43/00

166376, 166205, 166317

A flow conduit may have at least one orifice is in the vicinity of a flow source. The source is at least partially covered (and flow blocked by) an optional temporary coating or barrier. The flow pathway between the orifice and the source is temporarily blocked with a degradable material or barrier. The material disintegrates (e. g. under the influence of time or temperature) to optionally produce a product that removes the temporary coating in the area adjacent the barrier. The method is useful in one non-limiting context of recovering hydrocarbons where the flow conduit is the casing or liner of the well and the flow source is a subterranean reservoir where the temporary coating is a filter cake.

7597148, Oct 6, 2009

Apr 24, 2006

11/409687

Edward J. O'Malley - Houston TX, US
Bennett M. Richard - Kingwood TX, US
Paul M. McElfresh - Spring TX, US
Aftab Khokhar - Houston TX, US
Daniel L. Crosby - Sugar Lane TX, US
Vu Thieu - Houston TX, US
Roger W. Fincher - Conroe TX, US
Larry A. Watkins - Conroe TX, US

Baker Hughes Incorporated - Houston TX

E21B 28/00

166304, 166249, 166902, 175 68

Gas hydrates, particularly natural gas hydrates e. g. methane hydrates, may be formed and controlled within conduits and vessels by imparting energy to gas and water, for instance using agitation or vibration. The systems and methods allow for improved flow characteristics for fluids containing the gases, e. g. hydrocarbon fluids being transported, and for improved overall efficiencies. The gas and water within a gas flow path may be perturbed or agitated to initiate formation of relatively small hydrate particles. The hydrate particles continue to form as long as energy is imparted and water and hydrate guest molecules are available. High amplitude agitation of the gas and water will repeatedly break up agglomerated hydrate particles that form and encourage the formation of more and smaller particles. As more hydrate forms in this manner, less and less free water may be available proximate the gas and water contact.

7708073, May 4, 2010

Mar 5, 2008

12/042499

Bennett M. Richard - Kingwood TX, US
Paul M. McElfresh - Spring TX, US

Baker Hughes Incorporated - Houston TX

E21B 43/24

166302, 166228

A screen assembly has a material that conforms to the borehole shape after insertion. The assembly comprises a compliant layer that takes the borehole shape on expansion. The outer layer is formed having holes to permit production flow. The selected conforming material swells with heat, and in one non-limiting embodiment comprises a shape memory foam that is thermoset or thermoplastic. Heat is provided by supplying a fuel (including an oxidant) to a catalyst in close proximity to the compliant layer so that the product from the catalytic reaction is heated steam which contacts and deploys the conforming material. The base pipe can have a screen over it to act as an underlayment for support of the conforming layer or alternatively for screening.

7762342, Jul 27, 2010

Dec 4, 2008

12/328449

Bennett M. Richard - Kingwood TX, US
Paul McElfresh - Spring TX, US
Chad Williams - Kingwood TX, US

Baker Hughes Incorporated - Houston TX

E21B 29/02
E21B 43/00

166376, 166205, 166317

A flow conduit may have at least one orifice is in the vicinity of a flow source. The source is at least partially covered (and flow blocked by) an optional temporary coating or barrier. The flow pathway between the orifice and the source is temporarily blocked with a degradable material or barrier. The material disintegrates (e. g. under the influence of time or temperature) to optionally produce a product that removes the temporary coating in the area adjacent the barrier. The method is useful in one non-limiting context of recovering hydrocarbons where the flow conduit is the casing or liner of the well and the flow source is a subterranean reservoir where the temporary coating is a filter cake.

7879767, Feb 1, 2011

May 31, 2005

11/141492

Perry Douglas Baycroft - Houston TX, US
Allen D. Gabrysch - Houston TX, US
James B. Crews - Willis TX, US
Paul M. McElfresh - Spring TX, US

Baker Hughes Incorporated - Houston TX

E21B 43/27

507 90, 507219, 507239, 507244, 507245, 507246, 507248, 507261, 507262, 1663051

An aqueous, viscoelastic fluid gelled with a viscoelastic surfactant (VES) is inhibited against hydrate formation with an effective amount of an additive that could be one or more halide salts of alkali metals and alkali earth metals, formate salts, alcohols, glycols, glycol amines, sugars, sugar alcohols, amidoamine oxides, polymers such as polyamines, polyvinylpyrrolidones and derivatives thereof, polyvinyl alcohols and derivatives thereof, polycaprolactams and derivatives thereof, hydroxyethylcellulose, and mixtures thereof. These fluids are inhibited against hydrate formation and may have increased viscosity as well. The additives may increase viscosity to the point where less VES is required to maintain a given viscosity. These inhibited, aqueous, viscoelastic fluids may be used as treatment fluids for subterranean hydrocarbon formations, such as in stimulation treatments, e. g. hydraulic fracturing fluids.