CARBO CERAMICS INC.

A synthetic turf system includes a plurality of synthetic turf fibers and a plurality of ceramic pellets interspersed among the synthetic turf fibers. The ceramic pellets have a hardness on the Mohs scale of 6 to 8, a density of 0.5 to 2.15 g/cm 3 , and a sphericity and roundness rating of 0.7 to 0.99. The ceramic pellets include a mixture of alumina fines and at least one of kaolin or bauxite. The ceramic pellets are chemically inert and free from respirable quartz silica dust. The ceramic pellets may include a ceramic pellet core and a coating. The coating may be configured to control thermal properties of the ceramic pellets. The synthetic turf system may include small ceramic pellets configured to remain near a surface and large ceramic pellets configured to settle towards a bottom of the system.

Pellets for use in agricultural applications are disclosed herein. The pellets can include a porous substrate having an internal interconnected porosity. An agricultural treatment material can be disposed into at least a portion of the internal interconnected porosity of the porous substrate.

Electrically conductive proppants and methods for detecting, locating, and characterizing same are provided. The electrically conductive proppant can include a substantially uniform coating of an electrically conductive material having a thickness of at least 500 nm. The method can include injecting a hydraulic fluid into a wellbore extending into a subterranean formation at a rate and pressure sufficient to open a fracture therein, injecting into the fracture a fluid containing the electrically conductive proppant, electrically energizing the earth at or near the fracture, and measuring three dimensional (x, y, and z) components of electric and magnetic field responses at a surface of the earth or in an adjacent wellbore.

A method for evaluating induced fractures in a wellbore includes obtaining a first set of data in a wellbore using a downhole tool. The method also includes pumping a first proppant into the wellbore after the first set of data is obtained. The first proppant includes a first tracer that is not radioactive. The method also includes pumping a second proppant into the wellbore. The second proppant includes a second tracer that is not radioactive. The second tracer is different than the first tracer. The first proppant and the second proppant flow into fractures in the wellbore. The method also includes obtaining a second set of data in the wellbore using the downhole tool after the first and second proppants are pumped into the wellbore. The method also includes comparing the first and second sets of data.

A method of forming a consolidated proppant pack in a fracture of a subterranean formation. The method includes introducing a mixture of a plurality of unconsolidated resin-coated proppant particulates and a fracturing fluid into a well bore. The plurality of unconsolidated resin-coated particulates includes proppant particulates having a resin coating on an outer surface of each of the proppant particulates. The fracturing fluid includes a reactive crosslinker that is a fluid and is dispersed throughout the fracturing fluid as an emulsion. The resin-coated proppant particulates are contacted with the reactive crosslinker in the well bore at a crosslinking temperature, causing the reactive crosslinker to react with the resin-coated proppant particulates to form a consolidated proppant pack.

A method for producing cross-linked chemical treatment agent particles includes introducing a core pellet into a fluidizer. The method also includes mixing a chemical treatment agent with a cross-linker to provide a mixture and introducing the mixture to the fluidizer. The method also includes applying the mixture to the core pellet in the fluidizer to provide a cross-linked chemical treatment agent particle having a size from about 4 mesh to about 120 mesh. The mixture may be heated prior to or during contact with the core pellet.

A composition and method for hydraulically fracturing an oil or gas well to improve the production rates and ultimate recovery using a porous ceramic proppant infused with a chemical treatment agent is provided. The chemical treatment agent may be a tracer material that provides diagnostic information about the production performance of a hydraulic fracture stimulation by the use of distinguishable both water soluble and hydrocarbon soluble tracers. The tracer can be a biological marker, such as DNA. The porous ceramic proppant can be coated with a polymer which provides for controlled release of the chemical treatment agent into a fracture or well bore area over a period of time.

A method for producing an electrically-conductive pellet includes reducing a size of a first material. The method also includes wetting the first material to produce a first slurry. The method also includes introducing the first slurry into a fluidizer to produce a first pellet. The method also includes reducing a size of a second material. The second material is an electrically-conductive material. The method also includes wetting the second material to produce a second slurry. The method also includes applying the second slurry to the first pellet.

The present disclosure relates to material for use in oil and gas well completion activities. More particularly, the present disclosure relates to diversion particles, along with methods for making and using the diversion particles. In an embodiment, a composite diversion material includes a non-degradable component comprising two or more non-degradable particulates, wherein the non-degradable particulates have a long term permeability at 7,500 psi of at least about 20 D. The composite diversion material includes a degradable component surrounding at least a portion of the non-degradable component. In another embodiment, a method of making a composite diversion material includes mixing non-degradable proppant particles with an aqueous solution containing a first degradable material to provide a mixture having a proppant concentration of at least about 20 volume percent. The method includes drying the mixture at a temperature of from about 25° C. to about 200° C. to provide the composite diversion material.

The present disclosure is directed to methods for evaluating a gravel pack, a frac-pack, or cement in a wellbore. In at least one embodiment, a method for evaluating a gravel pack, frac-pack or cement in a wellbore, includes pumping a first material into the wellbore, wherein the first material comprises a first tracer that is not radioactive. The method includes pumping a second material into the wellbore, wherein the second material comprises a second tracer that is not radioactive. The method includes obtaining a set of data using the downhole tool in the wellbore after the first and second materials are pumped into the wellbore. The method includes obtaining a baseline using the downhole tool in the wellbore in a depth interval without the first or second material. The method includes comparing the set of data with the baseline.