Disclosed are surface-modified nanoparticles and surfactants used in compositions and methods for enhancing hydro-carbon recovery from subterranean formations.

Disclosed are surface-modified nanoparticles and surfactants used in compositions and methods for enhancing hydro-carbon recovery from subterranean formations.

The method enables enhanced recovery of oil contained in an underground oil reservoir by using an injection well including two passages of a water passage and a gas passage. The enhanced oil recovery method includes steps of injecting an injection water from the water passage, injecting an injection gas from the gas passage and spraying the injection gas as a fine gas bubble flow through a micro-bubble generator which is installed at a lower end of the gas passage, and penetrating into the underground oil reservoir a gas-liquid mixture fluid containing micro-bubbles generated by mixing the injection water and the fine gas bubble flow in the injection well.

In one example, an apparatus includes a TLT (Time of Flight (TOF)/LiDAR tool) with one or more optical transmitters and optical receivers that are operable to cooperate to obtain data concerning a downhole feature when the apparatus is deployed in a downhole environment. This apparatus further includes a first device operable to determine a position, speed, and/or orientation, of the TLT, when the TLT is deployed in the downhole environment, a second device configured to store locally and/or transmit the data to a location on a surface, a power source connected to the TLT, the first device, and the second device, and a housing within which the TLT, first device, second device, and power source are disposed, and the housing includes a connector configured to interface with a piece of downhole equipment.

An atomization generator and a special high-pressure atomization generation device for increasing oil and gas field recovery are provided. The special high-pressure atomization generation device for increasing oil and gas field recovery includes an agent pot assembly, a gear pump, a metering pump, an atomization generator and pipelines. The gear pump is connected with the agent pot assembly through an agent pot liquid inlet pipe. The metering pump is arranged between the agent pot assembly and the atomization generator which are connected through the low-pressure manifold pipeline and the high-pressure liquid inlet pipeline. The high-pressure liquid inlet pipeline is connected with the liquid inlet pipe. The liquid inlet pipes are connected with the metering pump. The gas inlet pipe is connected with the high-pressure gas source through the high-pressure gas inlet pipe. The gas inlet cap is provided with a gas inlet pipe.

Methods and systems for increasing normalized production rate of an oil and gas reservoir by optimizing a pressure drawdown of a subsurface formation are disclosed. The methods include determining permeability of the subsurface formation as a function of effective stresses, determining a stress sensitivity factor for the core sample, upscaling the sensitive stress factor, determining the optimum pressure drawdown for the subsurface formation, and controlling the pressure drawdown in a field operation such that it does not exceed the optimum pressure drawdown for the subsurface formation.

A process for recovering oil from an oil-bearing formation is disclosed comprising providing a first oil recovery formulation comprising a first surfactant able to create low interfacial tension with reservoir crude oil; injecting the first oil recovery formulation into the oil-bearing formation via an injection well (201); providing a second oil recovery formulation having a second surfactant with a higher solubility in water than the first formulation; injecting the second oil recovery formulation into the oil-bearing formation via the injection well; and producing oil to a production well (203).

A method and apparatus for controlling the flow of fluid in an injection well includes a main valve assembly having a valve and a retrievable nozzle selective lock assembly (RNSLA). The RNSLA is operable when positioned within the valve body to open the valve when fluid is pumped into the well and closes the valve when fluid flow is terminated. The RNSLA includes a replaceable orifice nozzle so that orifices of different dimensions may be used in conjunction with the valve assembly. In an alternate embodiment, the RNSLA includes a variable output nozzle assembly to maintain the valve in a protected open position without chattering over a wide range of flow rates.

A method and apparatus for controlling the flow of fluid in an injection well includes a main valve assembly having a valve and a retrievable nozzle selective lock assembly (RNSLA). The RNSLA is operable when positioned within the valve body to open the valve when fluid is pumped into the well and closes the valve when fluid flow is terminated. The RNSLA includes a replaceable orifice nozzle so that orifices of different dimensions may be used in conjunction with the valve assembly. In an alternate embodiment, the RNSLA includes a variable output nozzle assembly to maintain the valve in a protected open position without chattering over a wide range of flow rates.

This disclosure relates to methods of treating a subterranean formation or cement construction in the presence of one or more contaminants using a hydrogel composition that contains a poly-alkene maleic anhydride copolymer, a polyethylene glycol, and an aqueous carrier.