A vapor recovery apparatus degasses oil and water produced by an oil well. The apparatus has a first vessel forming a column. Oil containing gas enters the bottom of the first vessel and flows up to a liquid outlet. Heat is applied to the rising oil, wherein the oil foams. Gas escapes into the upper end. The foam flows into a second column and along a roughened surface. The bubbles in the foam break apart, releasing the gas. The oil flows down the second column to an outlet. Water is introduced into a third vessel. The water releases gas therein, which gas mingles with the gas from the oil. The third vessel is located around the first and second vessels. A compressor may be used to withdraw the gas and provide hot compressed gas to heat the rising oil in the first column.

A system may include an output manifold that may be in fluid communication with a reservoir and that may include multiple discharge ports. Each of the discharge ports may be configured to discharge electrorheological fluid into a housing. A recovery manifold may be in fluid communication with the reservoir and include multiple recovery ports. Each of the recovery ports may be configured to receive the electrorheological fluid from a housing. A gas remover may be positioned to extract gas from the electrorheological fluid received from the recovery ports. A housing may be connected to the system, and electrorheological fluid from the system may be pumped through the housing and the gas remover.

A degassing system includes a degassing tank with a first space area configured for having liquid introduced therein and a second space area configured for having the liquid from the first space area introduced therein. The first and the second space area are partially separated from one another by a separation element. The degassing system includes a controllable pump configured to pump liquid from the first space area to the second space area for a two-stage vacuum degassing process responsive to the pump being operated. The degassing system includes a control device configured to control the pump to not be operated for a single-stage vacuum degassing process and to be operated for a two-stage vacuum degassing process.

Systems and methods generate steam mixed with desired non-condensable gas concentrations using a direct steam generator. Injecting the steam into a reservoir may facilitate recovering hydrocarbons from the reservoir. Cooling an output of the direct steam generator produces water condensate, which is then separated from the non-condensable gas, such as carbon dioxide. Reducing pressure of the condensate subsequently heated by cross-exchange with effluent of the direct steam generator regenerates the steam with the carbon dioxide removed for the injection.

Systems and methods for separation of hydrocarbon containing fluids are provided. More particularly, the disclosure is relevant to separating fluids having a gas phase, a hydrocarbon liquid phase, and an aqueous liquid phase using indirect heating. In general, the system uses a first gas separation followed by pressure reduction and then a second gas separation. Indirect follows the second gas separation and then three-phase separation.

The present invention relates to an apparatus and method of preparing carbonate and/or formate from carbon dioxide. The apparatus of preparing carbonate and/or formate from carbon dioxide (CO.sub.2), comprising: an electrolysis reactor comprising (i) an anode which contains an aqueous solution of a Group I metal salt as an electrolytic solution, (ii) an ion-exchange membrane through which metal cations derived from the Group I metal salt and water flow from an anode to a cathode, (iii) a cathode, and (iv) a gas diffusion layer which supplies a carbon dioxide-containing gas to the cathode; a power supply unit of applying a voltage between the anode and the cathode; a first gas-liquid separator of recovering the electrolytic solution from the products formed in the anode; a second gas-liquid separator of recovering carbonate and/or formate from the products formed in the cathode; a pH meter of measuring the pH of the electrolytic solution recovered from the first gas-liquid separator; a first reactant supply unit of supplying (a) the electrolytic solution recovered from the first gas-liquid separator and (b) the aqueous solution of the Group I metal salt with which the recovered electrolytic solution is replenished according to the pH of the electrolytic solution, to the anode; and a second reactant supply unit of supplying carbon dioxide or a mixer comprising carbon dioxide and water vapor to the cathode; wherein, when a voltage is applied between the anode and the cathode, in the anode, water undergoes electrolysis to generate hydrogen ions, oxygen, and electrons, and metal cations in the Group I metal salt are substituted with the hydrogen ions, while the generated metal cations move to the cathode through the ion-exchange membrane and the electrons move to the cathode through an external electric line; and in the cathode, carbon dioxide, water, metal cations, and electrons are reacted and produce carbonate and/or formate.

The present system is for integrated management of associated gas and produced water at oil well extraction sites. The system includes a controller that makes gas allocation determination (e.g., directs conditioned gas to (i) gas flare, (ii) produced water reduction system, and/or (iii) generator) when a change in conditioned gas flow is detected based on first plurality of inputs. If the conditioned gas is directed to the generator, then the controller makes an electricity allocation determination (e.g., (i) increase a data processing operating rate on a data processing server, (ii) start up idle data processing equipment, (iii) direct generated electric current to a power grid, and/or (iv) charge a storage battery) based on second plurality of inputs. By operating the system of gas consumption and electricity production/consumption in an integrated fashion, benefits of flaring prevention, resource conversation, and more efficient economic operations are optimized to a degree not previously attainable.

A multi-functional slurry processing system (“VARCOR”) and associated methods is disclosed. The present examples provide a multi-functional slurry processing system incorporating systems and methods for separating liquid and solid components in slurries. In particular the systems and methods described herein produce clean water, dried solids, and potential concentration of desirable constituents with a boiling point lower than water. At least one example of the multi-functional slurry processing system provides a self-contained processing facility configured to efficiently convert high water-content slurries into its constituent solid and liquid fractions and subsequently generating and collecting clean water and concentrating desirable constituents with a boiling point lower than water. The multi-functional slurry processing system advantageously applies thermodynamic principles in a system which may include various combinations of a preheater, a degassing unit, a dryer, a steam filter, a compressor, a concentrating tower, and a condensation unit.

Provided are techniques that include operating a spiral contactor. The techniques include receiving, by a spiral contactor, a first fluid, and receiving a second fluid, wherein the first fluid is different than the second fluid. The techniques also include exchanging the first fluid and the second fluid using the spiral contactor, and outputting a deoxygenated fluid from the spiral contactor, wherein the deoxygenated fluid has a lower oxygen concentration than the first fluid.

Embodiments of the present invention are generally related to a system and method to remove hydrogen sulfide from sour water and sour oil. Particularly, hydrogen sulfide is removed from sour water and sour oil without the need for special chemicals, such as catalyst chemicals, scavenger chemicals, hydrocarbon sources, or a large-scale facility. The system and method in the present invention is particularly useful in exploratory oil and gas fields, where large facilities to remove hydrogen sulfide may be inaccessible. The present invention addresses the need for safe and cost-effective transport of the deadly neurotoxin. Particular embodiments involve a system and method that can be executed both on a small and large scale to sweeten sour water and sour oil.