A variety of systems, methods and compositions are disclosed, including, in one method, a method for well treatment may comprise providing a treatment fluid comprising an aqueous base fluid; and a nanofribril cellulose additive, wherein the nanofribril cellulose additive comprises nanofribril cellulose and a surfactant adsorbed onto a surface of the nanofribril cellulose; and introducing the treatment fluid into a well bore penetrating a subterranean formation. Additional systems, methods and compositions are also disclosed.

The diverting agent of the present invention contains resin particles of polyvinyl alcohol-based resin. The resin particles of polyvinyl alcohol-based resin are a particle mixture containing two or more types of resin particles having different particle diameters, and the diverting agent contains resin particles A of polyvinyl alcohol-based resin having a particle diameter of 1,700 μm or more in a range of 5 mass % to 95 mass % and resin particles B of polyvinyl alcohol-based resin having a particle diameter of 250 μm to 1,000 μm in a range of 5 mass % to 95 mass %.

The present disclosure provides water-based well treatment fluids methods of using such fluids in treating subterranean formations to prevent swelling and/or migration of fines. The water-based well treatment fluid contains an aqueous continuous phase and a clay stabilizing agent comprising less than 20% by weight, based on the total weight of the clay stabilizing agent, of an unhindered primary amine and a second amine selected from an alkanolamine, a polyalkylene polyamine, a compound having a formula R.sub.4—(CH.sub.2).sub.d—NH.sub.2 where R.sub.4 is a piperazino group or a morpholino group and d is an integer from 0 to 10, a compound having the formula where his an integer from about 2 to about 7 and a mixture thereof.

##STR00001##

A method may include supplying water for a mud mixture to a mixing tank according to a predetermined volume. The method may further include supplying, using a rheological sensor, a viscosifier to the mud mixture in the mixing tank until the mud mixture achieves one or more predetermined rheological values. The method may further include supplying, using a density sensor, a weighting agent to the mud mixture in the mixing tank until the mud mixture achieves a predetermined specific gravity value. The method may further include supplying, using a pH sensor, a buffering agent to the mud mixture in the mixing tank until the mud mixture achieves a predetermined pH value to produce a drilling fluid.

The present disclosure relates to subterranean formation operations and, more particularly, to embedded treatment fluid additives for use in subterranean formation operations. The embedded treatment additives may comprise an aqueous-soluble downhole reactive material embedded in a crosslinked polymeric solution to delay the reactivity of the aqueous-soluble downhole reactive material, thereby forming the embedded treatment additive, wherein the aqueous-soluble downhole reactive material is a solid.

The present disclosure relates to subterranean formation operations and, more particularly, to embedded treatment fluid additives for use in subterranean formation operations. The embedded treatment additives may comprise an aqueous-soluble downhole reactive material embedded in a crosslinked polymeric solution to delay the reactivity of the aqueous-soluble downhole reactive material, thereby forming the embedded treatment additive, wherein the aqueous-soluble downhole reactive material is a solid.

Water-based drilling fluids may include an aqueous base fluid and a mixture of polyethylene polyamines in an amount of from 1 lb.sub.m/bbl to 20 lb.sub.m/bbl relative to the total volume of the water-based drilling fluid. The polyethylene polyamines of the mixture may have a first chemical structure H.sub.2NCH.sub.2CH.sub.2(NHCH.sub.2CH.sub.2).sub.xNH.sub.2, where x may be an integer greater than or equal to 3. The average molecular weight of the polyethylene polyamines in the water-based drilling fluid having the first chemical structure may be from 200 g/mol to 400 g/mol. Methods for drilling a subterranean well with the water-based drilling fluids are also disclosed.

According to one or more embodiments of the present disclosure, water-based drilling fluids may include an aqueous base fluid and one or more additives. In embodiments, water-based drilling fluids may include a lubricant blend including at least oleic acid and palmitoleic acid. The sum of the volume percent of the oleic acid and palmitoleic acid may be from 0.1 vol. % to 10 vol. % of the total volume of the water-based drilling fluid. In embodiments, water-based drilling fluids may include a lesser melting point fraction of jojoba oil in an amount of from 0.1 vol. % to 10 vol. % relative to the total volume of the water-based drilling fluid. At least 90% of the lesser melting point fraction of jojoba oil may have a melting point less than or equal to 15° C. Methods for drilling subterranean wells with the water-based drilling fluids are also disclosed.

A drilling fluid may include a carrier and a lubricant composition. The lubricant composition includes ethylene bottoms heavy pyrolysis oil. For example, the heavy pyrolysis oil may be bottoms of a fractionated fuel oil product separated from ethylene gas produced by a cracking of a hydrocarbon feedstock in a furnace.

This disclosure provides compositions comprising a suspension package, wherein the suspension packaging consists of solids for suspending in one or more liquids, wherein the solids comprise at least one of: (1) diamond dust, nano-diamonds, or combinations thereof; (2) tungsten; (3) graphite, graphene, or combinations thereof; and (4) silicon carbide. Further, 0.25% through 6% by volume of the composition, with the one or more liquids being present, in a 14.0 ppg aqueous CaBr.sub.2 solution, provides a coefficient of friction of less than 0.06 at a temperature between 250° F. and 400° F. at any time up through 10 minutes after combination of the 0.25% through 6% by volume of the composition to the 14.0 ppg aqueous CaBr.sub.2.