Methods for delivering treatment chemicals into a subterranean formation using treatment fluids that include nanoemulsions are provided. In some embodiments, the methods include providing a treatment fluid including an aqueous base fluid and a nanoemulsion including a water-soluble internal phase, a water-soluble external phase, and a surfactant, the nanoemulsion being formed by mechanically-induced shear rupturing; and introducing the treatment fluid into at least a portion of a subterranean formation at or above a pressure sufficient to create or enhance at least one fracture in the subterranean formation.

The flow of well treatment fluids may be diverted from a high permeability zone to a low permeability zone within a fracture network within a subterranean formation by use of a mixture comprising a dissolvable diverter and a proppant. At least a portion of the high permeability zone is propped open with the proppant of the mixture and at least a portion of the high permeability zone is blocked with the diverter. A fluid is then pumped into the subterranean formation and into a lower permeability zone of the formation farther from the wellbore. The diverter in the high permeability zones may then be dissolved at in-situ reservoir conditions and hydrocarbons produced from the high permeability propped zones of the fracture network. The mixture has particular applicability in the enhancement of production or hydrocarbons from high permeability zones in a fracture network located near the wellbore.

A method of cementing a wellbore comprises combining a liquid additive with a cement slurry, the liquid additive comprising a metal gluconate, an alkali metal or an alkaline earth metal salt, an alkanolamine, a dispersant, and water to form a cementing composition; injecting the cementing composition into the wellbore; and allowing the cementing composition to set.

Compositions and methods for using those compositions to at least partially stabilize subterranean formations are provided. In one embodiment, the methods include providing a treatment fluid including an aqueous base fluid and an additive including a low molecular mass organic gelator; introducing the treatment fluid into at least a portion of a subterranean formation to contact at least a portion of the subterranean formation that includes shale; and allowing the additive to interact with the shale to at least partially stabilize the shale.

A composition, treatment fluid and method using hydrolyzable fines. A treatment fluid, which may optionally include a high solids content fluid (HSCF) and/or an Apollonianistic solids mixture, includes a fluid loss control agent comprising a dispersion of hydrolyzable fines, optionally with one or more of a surfactant, plasticizer, dispersant, degradable particles, reactive particles and/or submicron particles selected from silicates, γ-alumina, MgO, γ-Fe2O3, TiO2, and combinations thereof.

An oilwell treatment composition comprising (i) a solubilizing agent wherein the solubilizing agent comprises a saturated compound of the formula:

H—(OC.sub.aH.sub.2a).sub.x(OC.sub.bH.sub.2b).sub.y—OC.sub.cH.sub.2c+1

where a and b are each independently 1, 3, or 4; c is 1, 2 or 3; x and y each independently, are numbers ranging from 1 to 5; (ii) a solid acid precursor and (iii) an aqueous fluid wherein the mass ratio of the solubilizing agent to the aqueous solution is within the range of about 1:3 to about 1:5 and the mass ratio of the solubilizing agent to the solid acid precursor is within the range of about 3:1 to about 2:1.

Drill-in fluids disclosed herein comprise an aqueous base fluid, a viscosifier, a fluid loss control additive, and a degradable bridging agent comprising a degradable high strength polymetaphosphate material capable of undergoing an irreversible degradation downhole. The present disclosure further relates to a method for controlling fluid loss through a subterranean surface by using the drill-in fluid for form a filter cake on the subterranean surface. Also provided is a method of degrading a filter cake with an aqueous fluid or aqueous acidic fluid, wherein the filter cake is produced from the drill-in fluid. Further provided is a specific order of addition of constituents of the drill-in fluid, which results in improved filter cake performance and/or filter cake removal.

A lost circulation material (LCM) that includes spheres having radially distributed and substantially-straight protrusions to facilitate engagement (such as interlocking and entanglement) of the spheres, and methods of preventing lost circulation using the spheres. Each sphere has a plurality of protrusions to contact protrusions of adjacent spheres. The spheres may form plugs in channels, fractures, and other openings in a lost circulation zone. Additionally or alternatively, the spheres may form a bridge on which other LCMs may accumulate to seal openings in a lost circulation zone.

Loss circulation material (LCM) and method for treating loss circulation in a wellbore in a subterranean formation, including placing the LCM having a solid body with permeable portions or pores into the wellbore to dispose the LCM at the loss circulation zone, and collecting solids onto the LCM at the loss circulation zone to form a barrier. The LCM may be applied at a loss circulation zone in a hydrocarbon reservoir section of the subterranean formation, and upon subsequent hydrocarbon production the collected solids may be dislodged by the produced hydrocarbon to allow for hydrocarbon production through the permeable portions or pores of the disposed LCM.

A classification scheme for classifying sized bridging materials is disclosed. The scheme identifies a durability metric for the sized bridging materials. The scheme then identifies a value range having a higher relative strength and a lower relative strength. The sized bridging materials may then be tested according to the durability metric and associated with a relative strength based on the durability metric determined during the test.