A flow control module includes an inlet hub coupled to a first flow passage having a first flow bore, a flow meter associated with the first flow bore and positioned for top-down fluid flow, a choke disposed in a second flow passage having a second flow bore, the second flow passage coupled to a distal end of the first flow passage, and an outlet hub coupled to a distal end of the second flow passage, the outlet hub facing in a different direction from the inlet hub.

A system and method for monitoring or controlling an aerobic landfill bioreactor having a plurality of zones each including at least one well head. The system comprises: a gas extraction blower, a plurality of temperature sensors disposed in the well heads, an ex-situ relative humidity detector, an ex-situ gas constituent detector, an air injection system, a liquid injection system, and a controller. Landfill gas is extracted by the blower and it's temperature, relative humidity, and gas constituents are measured. The system further comprises a system of headers, isolation valves, and flow control valves which serve to isolate zones for measurement and/or air and liquid injection as well as control the flow of either the landfill gas extraction or liquid and air injection. The method involves measuring: temperature, relative humidity, and gas constituents of the extracted landfill gas. Advantageously, the ex-site placement of the sensors and detectors ensure that measurements are representative of the aerobic bioreactor operating parameters. The air and liquid injection systems are adjusted, based on the measured temperature, relative humidity, and gas constituents to optimize the operation of the aerobic landfill bioreactor.

A managed pressure drilling (MPD) manifold has one or more valves that are operable by one or more actuators configured to synchronize the opening of one or more passageways in the valves with the closing of one or more of the other passageways in the valves, in order to minimize the likelihood of error and reduce response time. The valves are configured to transition smoothly between positions without fully blocking fluid flow in the manifold while changing the flow direction. The synchronization may be achieved mechanically, electrically, hydraulic, and/or pneumatically. The actuators may be remotely controlled by a control unit having a processor and control logic software, based on data collected by one or more sensors in the MPD manifold. The positions of the valves of the MPD manifold may be automatically adjusted by the control unit via the actuators.

An oil and gas well carbon capture system includes a controller configured for minimizing or eliminating natural gas flaring and venting. A downhole pump is driven by a motor connected to the controller, which interactively operates a control valve. Controller inputs include gas pressures, pump motor speed and oil and gas delivery. The system is configured for separating production phases comprising oil, water and natural gas. A pressure transducer monitors output to gas sales, which can also be monitored with a digital flow meter. A carbon capture method for oil and gas production is also provided. The controls system maximizes downhole pump efficiency and oil and gas production by interactively monitoring and controlling well operating parameters. A method embodying the present invention optimizes well production and operating efficiency.

Disclosed herein are various embodiments of methods and systems for drilling an oil or gas well safely and efficiently using underbalanced or near-balanced drilling techniques, wherein the primary means of pressure control is a Annular Pressure Control Diverter positioned below the BOP stack, with a return flow pattern where no drilling fluid returns up the (traditional) annulus between the drill pipe and the production casing and instead drilling fluid returns up the annulus between the production casing and intermediate casing. Drilling fluid returns flow through a wellhead, instead of a flow spool conventionally located below an upper RCD, and hence to the drilling choke. This drilling approach eliminates the need for hydraulic fracturing and preserves the natural fracture system of the producing formation while providing additional safety measures. It also prevents the accidental or deliberate discharge or flaring of methane during drilling and production.

An assembly includes an inlet hub (112) coupled to a first flow passage (124) located within a flow control module, the first flow passage having a first flow bore, a flow meter (144) associated with the first flow bore and positioned for top-down fluid flow, a choke (109) disposed in a second flow passage (136) having a second flow bore, and an outlet hub (119) coupled to a distal end of the second flow passage. A system includes a flow control module assembly (902) having an inlet (912) and at least two outlets (914, 916), a main line (920) in fluid communication with the inlet, a first branch line (922) coupled to the main line and to a first outlet (916) of the at least two outlets, and a second branch line (924) coupled to the main line and to a second outlet (914) of the at least two outlets, and a tie-in connector (918) coupled to the inlet of the flow control module assembly.

A system for monitoring the erosion of internal components of a valve having a valve (200, 300, 400) which in turn comprising a body (44, 17, 24), a trim (46, 19, 26) and a seat (21, 28, 48) and at least an ultrasonic probe (22, 40, 29) able to transmit ultrasonic waves through the internal components and receive waves reflection through. In this system, the gaps between the internal components of the valve are closed and the distances between them are almost equal to zero so that the continuity between components is able to transfer the waves determining therefore the distance between the ultrasonic probe (22, 40, 29) and the internal component to be monitored.

A wellhead valve control system includes a removable actuator adapted to couple to a valve, the valve being operable via a first operational mode. The system also includes an actuator element associated with the removable actuator, the actuator element operable to modify the first operational mode of the valve to a second operational mode, the second operational mode being different from the first operational mode. The system further includes a control panel, positioned remotely from the valve, the control panel configured to control the actuator element to adjust a valve position in the second operational mode.

The modular managed pressured drilling system provides multiple skids with individual chokes and PRVs on the skids. These skids secure to one another to construct a modular MPD system that provides the proper equipment for the drilling operation. An inlet flow block and an outlet flow block are secured to each skid. The flow blocks provide multiple apertures to provide different pathways for the drilling fluid through the flow blocks. The flow blocks may direct the fluid through a first choke, a second choke, a pressure relief valve, or a bypass.

Electro-responsive hydrogel particles are flowed into a first wellbore formed in a subterranean formation. An electric circuit is established between the first wellbore and a second wellbore formed in the subterranean formation. An electric current is applied through the electric circuit, thereby exposing the electro-responsive hydrogel particles to an electric field and causing at least one of swelling or aggregation of the electro-responsive hydrogel particles to form a flow-diverting plug within the subterranean formation. Water is flowed into the first wellbore to increase hydrocarbon production from the second wellbore.