Abstract: An apparatus and a method for treating a subterranean formation comprising designing a treatment that comprises a composition, wherein the design comprises a pressure influence on a viscosity of the composition, and performing the treatment, wherein the composition is not an energized fluid. An apparatus and a method wherein the viscosity is at least partially estimated based on experimental rheological data collected at pressures below about 500 psi and/or at a pressure that is about 1 atm to about 2,000 atm.

Abstract: A method includes hydraulically fracturing a subterranean formation with a first treatment fluid and allowing the hydraulic fracture to close. The method includes preparing a second treatment fluid having a damage removal agent including carbon dioxide. The second treatment fluid further includes a proppant pack damage removal agent including an oxidizer, a radical initiator, an acid, a solvent, and/or other damage removal agents. The method further includes injecting the second treatment fluid into the subterranean formation at a downhole pressure below a fracturing pressure for the subterranean formation. The method includes holding pressure on the formation while the second treatment fluid enhances formation and proppant pack permeability, and flowing the second treatment fluid back to the surface.

Abstract: A method is given for treating a wellbore to increase the production of hydrocarbons from a subterranean formation penetrated by a wellbore, involving a period of injecting into the formation an aqueous injection fluid having a different chemical potential than the aqueous fluid in the formation. If there is water blocking, an osmotic gradient is deliberately created to cause flow of water into the injected fluid; hydrocarbon is then produced by imbibition. If the pore pressure in the water-containing pores in the formation is too low, an osmotic gradient is deliberately created so that water flows from the injected fluid into the water-containing pores, increasing the pore pressure and facilitating hydrocarbon production by imbibition. The method may be repeated cyclically. A semipermeable membrane may be created to enhance the osmosis. Wetting agents may be used to influence imbibition.

Abstract: Recovery of hydrocarbon fluid from low permeability sources is enhanced by introduction of a treating fluid. The treating fluid may include one or more constituent ingredients designed to cause displacement of hydrocarbon via imbibition. The constituent ingredients may be determined based on estimates of formation wettability. Further, contact angle may be used to determine wettability. Types and concentrations of constituent ingredients such as surfactants may be determined for achieving the enhanced recovery of hydrocarbons.

Abstract: Methods of treating a subterranean formation are disclosed, using a fluid including an essentially metal-free organic crosslinker selected from amines, diamines, poly amines, polyamino polymers, alcohols, polyols, polyhydroxy polymers, hydroxyl amines, peptides and proteins, combined with a polysaccharide or cellulosic material having oxidized functional groups. The fluid is then introduced into a wellbore penetrating the formation to contact the formation. The polysaccharide or cellulosic material may have aldehyde groups as one example of an oxidized group, or any other suitable oxidized functional group. The polysaccharide or the cellulosic material may be oxidized using at least one of an enzymes, oxidizers, photooxidation, bacteria, catalyst, or other suitable technique. The fluid may also further include an inorganic crosslinker.

Abstract: In one embodiment, a system includes a cased wellbore disposed in a formation of interest. The system includes an emulsion positioned in the wellbore at a depth of the formation of interest. The emulsion includes an oil external phase and an aqueous internal phase. The oil external phase includes particles having calcium hydroxide. The aqueous internal phase includes insoluble silica particles. The system further includes a perforating tool that generates perforation tunnels through the cased wellbore into the formation of interest. The system further includes a well flow control device that shuts in the wellbore for a specified period of time. The emulsion breaks during contact with the formation in the perforation tunnels, and the calcium hydroxide and silica particles form a cementitious material that consolidates the perforation tunnels.

Abstract: In one embodiment, a system includes a cased wellbore disposed in a formation of interest. The system includes an emulsion positioned in the wellbore at a depth of the formation of interest. The emulsion includes an oil external phase and an aqueous internal phase. The oil external phase includes particles having calcium hydroxide. The aqueous internal phase includes insoluble silica particles. The system further includes a perforating tool that generates perforation tunnels through the cased wellbore into the formation of interest. The system further includes a well flow control device that shuts in the wellbore for a specified period of time. The emulsion breaks during contact with the formation in the perforation tunnels, and the calcium hydroxide and silica particles form a cementitious material that consolidates the perforation tunnels.

Abstract: A delivery unit for providing aggregate to a worksite, such as a wellsite location. The unit may include a mobile chassis for accommodating a plurality of modular containers which in turn house the aggregate. As such, a weight measurement device may be located between each container and the chassis so as to monitor aggregate levels within each container over time. The units may be particularly well suited for monitoring and controlling aggregate delivery during a fracturing operation at an oilfield. The modular containers may be of an interchangeable nature. Furthermore, a preferably wireless control device may be provided for monitoring and directing aggregate delivery from a relatively remote location.

Abstract: The invention discloses treatment and reuse of oilfield produced water. A method of inhibiting enzymes/bacteria in an aqueous medium for viscosification comprises contacting the aqueous medium with a denaturant and/or a bactericide and thereafter mixing a gelling agent in the aqueous medium. The viscosified fluid can be used as a well treating fluid for fracturing and other applications. A well treatment fluid comprises a metal denaturant and/or a bactericide and a gelling agent in an amount effective to viscosify the fluid. Also disclosed is oilfield produced water denatured with from 1 to 2000 ppm by weight of a zirconium compound.

Abstract: A well treatment fluid composition that comprises a carrier fluid and an amphoteric surfactant, and optionally a viscosifying agent and proppant, is well suited for use in fracturing coal beds to stimulate methane production. The composition preferably is a foam that comprises a gas such as nitrogen or air. Preferably, the surfactant has the formula R—NH2—(CH2)n—C(O)OX wherein R is a saturated or unsaturated alkyl group having from 6-20 carbon atoms, n is from 2-6, and X is hydrogen or a salt forming cation.

Abstract: Methods are provided for stimulation of hydrocarbon production from low permeability formations by hydraulic fracturing, acid fracturing, and hydraulic fracturing followed by gravel packing in a single operation. The methods use a first injected viscous pad made with low concentration uncrosslinked polymer to initiate and propagate the fracture and control fluid loss, followed by a second injected fluid gelled with a viscoelastic surfactant for carrying proppant or acid into the fracture.

Abstract: A well treatment fluid composition that comprises a carrier fluid and an amphoteric surfactant, and optionally a viscosifying agent and proppant, is well suited for use in fracturing coal beds to stimulate methane production. The composition preferably is a foam that comprises a gas such as nitrogen or air.

Abstract: A well treatment fluid composition that comprises a carrier fluid and an amphoteric surfactant, and optionally a viscosifying agent and proppant, is well suited for use in fracturing coal beds to stimulate methane production. The composition preferably is a foam that comprises a gas such as nitrogen or air. Preferably, the surfactant has the formula R—NH2—(CH2)n—C(O)OX wherein R is a saturated or unsaturated alkyl group having from 6-20 carbon atoms, n is from 2-6, and X is hydrogen or a salt forming cation.

Abstract: Methods are provided for increasing the production of hydrocarbons from shaly formations that contain adsorbed condensed hydrocarbon gases by treating such formations with dewatering compositions comprising surfactants that cause the surfaces of the formation to be or to remain oil-wet. The methods may be used in stimulation (acidizing or acid fracturing or hydraulic fracturing), remediation or workover, and in enhancing flow from natural fractures or from unstimulated formations.

Abstract: A well treatment fluid composition that comprises a carrier fluid and an amphoteric surfactant, and optionally a viscosifying agent and proppant, is well suited for use in fracturing coal beds to stimulate methane production. The composition preferably is a foam that comprises a gas such as nitrogen or air.

Abstract: Methods are provided for stimulation of hydrocarbon production from low permeability formations by hydraulic fracturing, acid fracturing, and hydraulic fracturing followed by gravel packing in a single operation. The methods use a first injected viscous pad made with low concentration uncrosslinked polymer to initiate and propagate the fracture and control fluid loss, followed by a second injected fluid gelled with a viscoelastic surfactant for carrying proppant or acid into the fracture.

Abstract: Methods are provided for increasing the production of hydrocarbons from shaly formations that contain adsorbed condensed hydrocarbon gases by treating such formations with dewatering compositions comprising surfactants that cause the surfaces of the formation to be or to remain oil-wet. The methods may be used in stimulation (acidizing or acid fracturing or hydraulic fracturing), remediation or workover, and in enhancing flow from natural fractures or from unstimulated formations.

Abstract: The improved recovery of hydrocarbons from subterranean formations by fracturing and matrix acidizing a subterranean formation is accomplished. Well treatment fluids having a viscoelastic surfactant fluid containing worm like micelles are useful to improve recovery of hydrocarbons and limit the loss of fracturing fluid into the formation fracture face. The viscolastic surfactant-based fracturing fluids of the present Invention are stable across a wide pH spectrum, allowing them to be used for fracturing treatments at low pH, as well as matrix acidizing treatments. In addition, the stability of these fluids is enhanced in the presence of organic anions. Two-stage fracturing treatments comprised of a viscoelastic surfactant-based fracturing fluid and a polymer-based system, wherein the two fluids are either blended or pumped into the formation sequentially (the polymer last) are also presented.

Abstract: The present Invention relates to hydrocarbon well stimulation, and more particularly to methods and compositions to remove (or more generally to transfer) fluid introduced into the subsurface. For instance, preferred methods involve creating then exploiting a capillary pressure gradient at the fracture face to induce fluid flow from the fracture into the formation thereby increasing effective fracture length, and then improving fracture conductivity.

Abstract: The present Invention relates to method to stimulate the production of hydrocarbons from a subterranean formation. In particular, the present Invention discloses and claims methods to enhance the removal of fracturing fluid from a fracture deliberately created in the formation, thereby increasing effective fracture length, and thereby increasing hydrocarbon production. The methods of the present Invention involve breaker schedules opposite conventional teaching—i.e., according to the Invention, the breakers are staged such that the fluid near the fracture tip breaks first creating a viscosity gradient which causes the fluid resident in the tip to move towards the wellbore where it is more easily removed.