A method for improved prediction and enhancement of hydrocarbon recovery from ultra-tight/unconventional reservoirs for both the primary production and any subsequent solvent huff‘n’puff periods based on facilitating the diffusion process may include steps of defining one or more initial properties of a reservoir and integrating characterization data of the reservoir; defining a wellbore trajectory for each of at least one well and one or more parameters associated with a completion/reservoir stimulation design; specifying operating conditions for a current development cycle; performing diffusion-based dynamic fracture/reservoir simulation for calculating hydrocarbon recovery and efficiency of a hydrocarbon process; and; determining whether to commence or continue enhanced oil recovery (EOR) or enhanced gas recovery (EGR) cycles.

A method includes selecting a model for a simulation of hydrocarbon recovery from a reservoir having a plurality of fractures during injection of an injected gas into the plurality of fractures. Selecting the model includes determining a flux ratio of a convection rate to a diffusion rate for the reservoir, determining whether the flux ratio is less than a threshold, and in response to the flux ratio being less than the threshold, selecting the model that includes diffusion. Selecting the model includes performing the simulation of the hydrocarbon recovery from the reservoir based on the model.

Techniques including methods, apparatus and computer program products are disclosed for determining an amount of hydrocarbon recoverable from porous reservoir rock by a miscible gas flood. The techniques include retrieve a representation of a physical porous reservoir rock sample (porous reservoir rock), the representation including pore space and grain space data corresponding to the porous reservoir rock, subsequent to an execution of a multiphase flow simulation to obtain predictions of flow behavior of oil in the presence of a waterflood of the porous reservoir rock, locate substantially immobile oil blobs or patches in the retrieved representation of the porous reservoir rock; and for N number of substantially immobile oil blobs or patches (blobs), evaluate changes in mobility of the blobs for two or more iterations an effort level for of a given EOR technique, with a first one of the two or more iterations expending a first level of effort and a second one of the two or more iterations expending a second, higher level of effort, to estimate an amount of change in mobilization of the blob between the first and the second iterations for the given EOR technique.

Systems, methods, and computer program products can be used for determining the amount of oil removed by a miscible gas flood. One of the methods includes identifying locations of oil within a volume representing a reservoir rock sample. The method includes identifying locations of gas within the volume. The method also includes determining the amount of oil removed based on locations within the volume where oil is either coincident with the gas or is connected to the gas by a continuous oil path.

Nanogas dispersions including an electrochemically activated (“ECA”) aqueous solution having an electrolyte and water; and a plurality of gas-filled cavities (i.e., nanobubbles) dispersed within the ECA aqueous solution. An enhanced oil recovery system including a reservoir containing an ECA aqueous solution; a nanogas dispersion generator configured to generate a nanogas dispersion within the ECA aqueous solution, the nanogas dispersion having the ECA aqueous solution and a plurality of nanobubbles dispersed therein; and an injection pump connected to the reservoir and configured to pump an effective amount of the nanogas dispersion into a subterranean formation. A method for treating a subterranean formation including: providing a nanogas dispersion made of an ECA aqueous solution and a plurality of nanobubbles; pumping an effective amount of the nanogas dispersion into the subterranean formation; and extracting a mixture of water from the subterranean formation to a surface-located device.

Systems, methods, and computer program products can be used for determining the amount of oil removed by a miscible gas flood. One of the methods includes identifying locations of oil within a volume representing a reservoir rock sample. The method includes identifying locations of gas within the volume. The method also includes determining the amount of oil removed based on locations within the volume where oil is either coincident with the gas or is connected to the gas by a continuous oil path.

A multi-level cross-district surface well pattern deployment method is provided. Firstly, a horizontal well is drilled from a location on a land surface corresponding to a junction H.sub.1 of a district rise coal pillar of the first district C.sub.1 in a first level and an upper mine field boundary coal pillar. A multilateral well is drilled from a location on the land surface corresponding to a junction H.sub.3 of a level coal pillar between the first and second levels, and the district rise coal pillar of the first district C.sub.1 in the first level. Liquid nitrogen is injected for permeability improvement after a gas drainage quantity decreases to 20% of an initial quantity. Gas drainage is repeated multiple times until the drainage quantity of coal bed methane through a gas drainage pipe of the horizontal pipe is reached 3 m.sup.3/min.

A tool includes a device including a housing and a rotor, the rotor to rotate about a longitudinal axis, and an axial gap generator including a stator assembly positioned adjacent to the rotor. The axial gap generator generates a voltage signal as a function of a gap spacing between the stator assembly and the rotor, the gap spacing being parallel to the longitudinal axis.

A system for producing CO and CO.sub.2 to achieve an efficient oil recovery operation having de minimis undesirable gaseous emissions is provided. The system includes a portable CO producing device and a portable CO.sub.2 producing device located proximate to the reservoir and a gas collecting device configured to receive CO and CO.sub.2 and selectively distribute a desired ratio of CO and CO.sub.2 dynamically based on current reservoir conditions. Producing CO.sub.2 proximate to the reservoir comprises reforming carbon based fuel within oxygen. Electrical energy generated is used to selectively distribute the desired ratio of CO/CO.sub.2 to the reservoir with de minimis greenhouse gases produced transmitted into the atmosphere. The system is an energy efficient arrangement that recycles and reuses by-products and unused products from the process. Greenhouse gas emissions are significantly reduced compared to conventional processes by-products are fully utilized. Hydrogen produced can be used to generate electricity, as can heat generated from other sources within the process.

The invention provides a method for optimizing production of a hydrocarbon well with a local controller supported from a supervisory control and data acquisition (SCADA) system. The method comprises calculating, at the local controller, optimal targets for one or more well parameters using measured values associated with operation of the hydrocarbon well. The method further comprises obtaining, at the local controller, a model that comprises a relationship between an operation of a gas injection choke and an operation of a production choke with the one or more well parameters based on the measurement values and received model parameters from the SCADA system. The method also comprises determining, at the local controller, operating set points based on the model for control of at least one of the production choke and the gas injection choke; and operating at least one of the production choke and the gas injection choke for optimized production.