A composition for reducing the viscosity of heavy oils, comprising a mixture of terpene and petroleum distillate wherein the mixture has a flash point of at least 95° C.

Cementing compositions containing a hydraulic cement, halloysite nanoparticles, and silica flour. The cementing compositions may optionally include other additives such as a friction reducer, a defoamer, and a fluid loss additive. Cement samples made therefrom and methods of producing such cement samples are also specified. The addition of halloysite nanoparticles and silica flour provides enhanced mechanical strength (e.g. compressive strength, flexural strength) and improved durability (e.g. resistance to CO.sub.2 and salinity) to the cement, making them suitable cementing material for oil and gas wells.

Cementing compositions containing a hydraulic cement, halloysite nanoparticles, and silica flour. The cementing compositions may optionally include other additives such as a friction reducer, a defoamer, and a fluid loss additive. Cement samples made therefrom and methods of producing such cement samples are also specified. The addition of halloysite nanoparticles and silica flour provides enhanced mechanical strength (e.g. compressive strength, flexural strength) and improved durability (e.g. resistance to CO.sub.2 and salinity) to the cement, making them suitable cementing material for oil and gas wells.

Methods for creating or enhancing a fracture in a subterranean formation include introducing a pad fluid into a formation at a rate and pressure sufficient to create or enhance at least one fracture therein. The pad fluid can include a pad base fluid, micro-proppant particulates, a gas-generating chemical, and an activator, and wherein either the gas-generating chemical or the activator or both are encapsulated. The methods can include placing the micro-proppant particulates, etc. into the fracture; releasing the activator from its encapsulation; reacting the gas-generating chemical and the activator in the fracture so as to generate gas and heat, thereby creating or enhancing at least one microfracture therein; introducing a fracturing fluid into the formation, wherein the fracturing fluid comprises a fracturing base fluid and macro-proppant particulates and placing the macroproppant particulates into the fracture so as to form a proppant pack therein.

Methods for creating or enhancing a fracture in a subterranean formation include introducing a pad fluid into a formation at a rate and pressure sufficient to create or enhance at least one fracture therein. The pad fluid can include a pad base fluid, micro-proppant particulates, a gas-generating chemical, and an activator, and wherein either the gas-generating chemical or the activator or both are encapsulated. The methods can include placing the micro-proppant particulates, etc. into the fracture; releasing the activator from its encapsulation; reacting the gas-generating chemical and the activator in the fracture so as to generate gas and heat, thereby creating or enhancing at least one microfracture therein; introducing a fracturing fluid into the formation, wherein the fracturing fluid comprises a fracturing base fluid and macro-proppant particulates and placing the macroproppant particulates into the fracture so as to form a proppant pack therein.

The present invention relates to an in situ staged steam extraction method for removing petroleum products from a heavy oil or bitumen reservoir from subterranean locations. Specifically, each injection stage comprises a different steam composition. A steam composition may consist essentially of steam or may comprise one or more enhanced oil recovery agent.

The present invention relates to an in situ staged steam extraction method for removing petroleum products from a heavy oil or bitumen reservoir from subterranean locations. Specifically, each injection stage comprises a different steam composition. A steam composition may consist essentially of steam or may comprise one or more enhanced oil recovery agent.

A process includes: (a) injecting a steam composition into a subterranean location containing bitumen, the steam composition containing an alkylene glycol ether and steam, wherein the alkylene glycol ether is other than a glycol ether amine; and (b) recovering bitumen from the subterranean location to above the ground.

A process includes: (a) injecting a steam composition into a subterranean location containing bitumen, the steam composition containing an alkylene glycol ether and steam, wherein the alkylene glycol ether is other than a glycol ether amine; and (b) recovering bitumen from the subterranean location to above the ground.

A method is provided for producing upgraded heavy oil from a subterranean reservoir by producing a steam chamber within the reservoir by the action of steam and flowing a liquid phase additive into a near wellbore region of the steam chamber to control asphaltenes mobility within the near wellbore region. Build-up of asphaltenes, which derive from the heavy oil, in the near wellbore region has the potential of affecting heavy oil production rates from the reservoir. The additive is formulated to mobilize the asphaltenes within this region.