Abstract: A cement slurry may be separated from a drilling mud in a wellbore by introducing into the wellbore an aqueous fluid having a weighting agent, a hydratable gellant powder having a particle size distribution from about 150 to about 300 mesh; and a suspension agent of particulates of a resin encapsulated hydratable polymeric viscosifying agent, the suspension agent having a particle size distribution such that at least 90% of the particulates are retained on a 20 mesh screen and 100% of the particulates are retained on a 6 mesh screen. The weighting agent may be suspended in the viscous fluid by hydrating the hydratable gellant powder. At higher temperatures and after degradation of the hydrated gellant, the weighting agent remains suspended by degrading the resin of the suspension agent and releasing the hydratable polymeric viscosifying agent into the wellbore.

Abstract: A cement slurry may be separated from a drilling mud in a wellbore by introducing into the wellbore an aqueous fluid having a weighting agent, a hydratable gellant powder having a particle size distribution from about 150 to about 300 mesh; and a suspension agent of particulates of a resin encapsulated hydratable polymeric viscosifying agent, the suspension agent having a particle size distribution such that at least 90% of the particulates are retained on a 20 mesh screen and 100% of the particulates are retained on a 6 mesh screen. The weighting agent may be suspended in the viscous fluid by hydrating the hydratable gellant powder. At higher temperatures and after degradation of the hydrated gellant, the weighting agent remains suspended by degrading the resin of the suspension agent and releasing the hydratable polymeric viscosifying agent into the wellbore.

Abstract: A method of cementing a wellbore comprises injecting into the wellbore a cement slurry comprising an encapsulated accelerant comprising an accelerant encapsulated within an encapsulation material; a cementitious material; and an aqueous carrier; and releasing the accelerant from the encapsulation material.

Abstract: A downhole system (10, 110, 210) includes a tubular (18) having a longitudinal axis (32), and a trace (46) applied on the tubular (18). The trace (46) includes a conductive portion (60) formed from an electrically conductive material (58) and the trace (46) is configured to deliver a signal between uphole and downhole locations of the tubular (18).

Abstract: A sensor configuration including a centralizer having a rib, a hollow defined within the rib, and a sensor positioned within the hollow. A borehole system including a borehole, a tubular string disposed within the borehole, a centralizer having a rib, and the rib defining a hollow, disposed upon the tubular string, a sensor within the hollow. A method for acquiring data in a borehole including running a sensor configuration as in any prior embodiment on a tubular string into a borehole, cementing the tubular string in the borehole, and sensing with the sensor configuration, a parameter in the borehole.

Abstract: A method of cementing a wellbore penetrating a subterranean formation comprises blending a base cement slurry with one or more liquid additives to provide a cementing composition, the base cement slurry comprising a liquid carrier, a class G cement or a blend of class G and class C cements as defined by the American Petroleum Institute (API) Specification 10A standards (R2015), and silica fume, or fumed silica, or a combination of silica fume and fumed silica, the base cement slurry having a density of about 14 to about 16 ppg; and injecting the cementing composition into the wellbore. The single base cement slurry can be used globally to make cementing compositions having wide ranges of density and temperature stability.

Abstract: A method of cementing a wellbore penetrating a subterranean formation comprises blending a base cement slurry with one or more liquid additives to provide a cementing composition, the base cement slurry comprising a liquid carrier, a class G cement or a blend of class G and class C cements as defined by the American Petroleum Institute (API) Specification 10A standards (R2015), and silica fume, or fumed silica, or a combination of silica fume and fumed silica, the base cement slurry having a density of about 14 to about 16 ppg; and injecting the cementing composition into the wellbore. The single base cement slurry can be used globally to make cementing compositions having wide ranges of density and temperature stability.

Abstract: A downhole system (10, 110, 210) includes a tubular (18) having a longitudinal axis (32), and a trace (46) applied on the tubular (18). The trace (46) includes a conductive portion (60) formed from an electrically conductive material (58) and the trace (46) is configured to deliver a signal between uphole and downhole locations of the tubular (18).

Abstract: A downhole system includes a tubular having a longitudinal axis, and a conductive trace applied on the tubular. The conductive trace is configured to deliver a signal between uphole and downhole locations of the tubular.

Abstract: A zone isolation cementing system includes a tubular having a longitudinal axis and a first flow-controlled port, a first conduit having a first end and a second end, the first end fluidically connected to the first flow-controlled port, a first distributor manifold arranged to deliver cement slurry exteriorly of the tubular, the second end of the first conduit fluidically connected to the first distributor manifold, and a first settable packer disposed exteriorly of the tubular and arranged longitudinally between the first flow-controlled port and the first distributor manifold.

Abstract: A zone isolation cementing system includes a tubular having a longitudinal axis and a first flow-controlled port, a first conduit having a first end and a second end, the first end fluidically connected to the first flow-controlled port, a first distributor manifold arranged to deliver cement slurry exteriorly of the tubular, the second end of the first conduit fluidically connected to the first distributor manifold, and a first settable packer disposed exteriorly of the tubular and arranged longitudinally between the first flow-controlled port and the first distributor manifold.