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AssigneeHalliburton Energy Services, Inc.
InventorsLucas David Albrighton, Adam Matthew McKay, Paul Joseph Jones, Evan Baker Grimes, Evan Thomas Russell, Dominik Fry, Ryan Edward Barker, Sears T. Dealy, B. Raghava Reddy
Estimating the term…
Fluid additives suitable for use in a wellbore (e.g., a liquid comprising an aqueous miscible fluid, a liquid surfactant, or both) may be converted into a liquid-infiltrated porous silica that is a flowable bulk solid. The flowable bulk solid may then be handled and stored as a traditional solid wellbore additive. For example, the flowable bulk solid may be added to an aqueous fluid to produce a wellbore fluid that is then introduced into a wellbore penetrating a subterranean formation.
A method comprising:
A system comprising:
A method comprising:
Dependencies are inferred from the claim text.
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Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells: using "spacer" compositions
Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic…
Well-drilling compositions: non-aqueous well-drilling compositions, e.g. oil-based
Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations:…
About 8 years 4 months of term left · ends 4 Mar 2035 (estimated)
The embodiments described herein relate to wellbore additives.
Wellbore fluids are often complex formulations that include several additives that are typically mixed on-site. The wellbore additives used often include both liquid additives (e.g., liquid surfactants and aqueous-miscible solvents) and solid additives (e.g., weighting agents, cements, and fluid loss control agents). Using both solid and liquid additives when producing a wellbore fluid often requires multiple pieces of equipment, additional storage facilities, and increased manpower to prepare the wellbore fluid and maintain the equipment. The additional equipment, storage facilities, and manpower can increase the cost of the wellbore operations.
The following FIGURES are included to illustrate certain aspects of the embodiments, and should not be viewed as exclusive embodiments. The subject matter disclosed is capable of considerable modifications, alterations, combinations, and equivalents in form and function, as will occur to those skilled in the art and having the benefit of this disclosure.
FIG. 1 depicts an embodiment of a system configured for delivering a wellbore fluid to a downhole location according to at least some embodiments described herein.
The embodiments described herein relate to wellbore additives. More specifically, the embodiments described herein relate to liquid additives converted to solid additives, specifically, as liquid-infiltrated porous silica (LIPS), and the use of LIPS in flowable bulk solid wellbore additives.
As used herein, the term “flowable bulk solid” refers to powders, particulates, or mixtures thereof that have less than a 45° angle of repose according to ASTM D6393-14, Section 1.3.1: Measurement of Carr Angle of Repose). A flowable bulk solid may consist of a single component (e.g., the LIPS described herein) or multiple components (e.g., the LIPS described herein in combination with weighting agents).
As used herein, the terms “liquid-infiltrated porous silica” and “LIPS” refers to a porous silica particle having liquid-infiltrated into the pores of the particle. The LIPS described herein that are included in the flowable bulk solids have an amount of liquid-infiltrated into the pores of the silica particles such that the LIPS are flowable (i.e., have less than a 45° angle of repose according to ASTM D6393-14, Section 1.3.1: Measurement of Carr Angle of Repose).