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 junction and an outlet flow junction are secured to each skid. The flow junctions provide multiple ports to provide different pathways for the drilling fluid through the flow junctions. The flow junctions may direct the fluid through a first choke, a second choke, a pressure relief valve, or a bypass.

Aspects of the present disclosure relate to valve skid apparatus and related methods for wellhead systems. A check block of the check valve includes a check side face that interfaces with a gate side face of a gate block of the gate valve. A pump side block is coupled to the gate valve, and a well side block is coupled to the check valve. A first pressure relief valve is coupled to a top face of the pump side block, and a first bleed-off valve is coupled to a top face of the first pressure relief valve. A second pressure relief valve is coupled to a top face of the well side block, and a second bleed-off valve is coupled to a top face of the second pressure relief valve.

A well tool assembly to cut a wellhead gate valve by water jetting includes a water jetting head lowered into a wellhead tree coupled to a wellbore. The head includes a housing, an orifice plate and a jetting port. The housing defines a tubular region to receive water. The orifice plate is positioned within the tubular region downstream of a first end and upstream of a second end of the housing, and defines an orifice to accelerate a flow rate of the water received at a first flow rate upstream of the orifice plate to a second flow rate, greater than the first, downstream of the plate. At the second flow rate, the water can mill a gate valve within the wellhead. The jetting port is downstream of the orifice plate, and can receive the water at the second flow rate and guide the received water to the gate valve.

Disclosed herein are various embodiments of a method for minimizing formation damage while drilling an oil or gas well. An Annular Pressure Control Diverter is designed to be positioned below the conventional blowout preventer stack, and is activated during near balanced drilling operations to seal the annulus between the drill pipe and the production casing. Returned drilling fluid and produced fluids are diverted up the annulus between the production casing and intermediate casing and through a well head located below an all-inclusive BOP stack. The seal elements within the Annular Pressure Control Diverter do not rotate. Doors are provided on each side of the Annular Pressure Control Diverter to permit changing of the seal elements. The Annular Pressure Control Diverter also is used to ensure the capture of methane while drilling in a hydrocarbon bearing reservoir.

A method involves obtaining a current production rate, obtaining a current wellhead pressure, computing a current smoothed production rate from the current production rate, computing a current smoothed wellhead pressure from the current wellhead pressure, predicting based on the current smoothed production rate, the current smoothed wellhead pressure, and the current surface choke size, a future smoothed production rate and a future smoothed wellhead pressure, computing a change of the future vs the current smoothed production rate, and computing a change of the future vs the current smoothed wellhead pressure. The method further involves comparing the change of the future vs the current smoothed production rate against a first pre-specified threshold production rate derivative, comparing the change of the future vs the current smoothed wellhead pressure against a first pre-specified threshold wellhead pressure derivative, and based on an outcome of the comparison, determining whether future sanding is detected.

A valve assembly can include a housing having multiple longitudinally spaced apart ports, a sleeve longitudinally displaceable in the housing, and at least one deflector ring configured to block flow through an annular space formed between the housing and an outer surface of the sleeve. The deflector ring is positioned longitudinally between an adjacent pair of the ports. Another valve assembly can include a housing having a port, a sleeve longitudinally displaceable in the housing, and a nozzle having an orifice in communication with the port. The nozzle is secured to the housing.

A drilling system includes a choke valve system in fluid communication with a wellbore via a fluid return line. The choke valve system is configured to receive a return fluid from the wellbore. The choke valve system includes a choke valve through which the return fluid flows and a valve position sensor configured to determine a position of the choke valve. The drilling system further includes a controller in signal communication with the valve position sensor. The controller is programmed to determine a flow rate of the return fluid through the fluid return line based on the determined position of the choke valve. The controller is further programmed to adjust the position of the choke valve in response to the determined flow rate of the return fluid.

A method is for constructing a subsea well and an associated unit. The method may include: providing a unit having at least one component of a flow control assembly, the flow control assembly to be operable for controlling a flow of injection or production fluid during operation of the well after the well has been constructed; lowering the unit through sea toward a seabed; receiving part of the unit in a subsurface of the seabed to anchor the unit in place, part of the unit projecting above the seabed, whereby the component of the flow control assembly is positioned in the projecting part; and performing at least one well construction operation through a bore in the unit.

Systems and methods for generating and a controller for controlling generation of geothermal power in an organic Rankine cycle (ORC) operation in the vicinity of a wellhead during hydrocarbon production to thereby supply electrical power to one or more of in-field operational equipment, a grid power structure, and an energy storage device. In an embodiment, during hydrocarbon production, a temperature of a flow of wellhead fluid from the wellhead or working fluid may be determined. If the temperature is above a vaporous phase change threshold of the working fluid, heat exchanger valves may be opened to divert flow of wellhead fluid to heat exchangers to facilitate heat transfer from the flow of wellhead fluid to working fluid through the heat exchangers, thereby to cause the working fluid to change from a liquid to vapor, the vapor to cause a generator to generate electrical power via rotation of an expander.

Adjustable chokes used during the hydraulic fracturing process are exposed to excessive wear and tear due to high pressures, sand, and various proppants extracted along with the fluids. Often it is simply the tip of the stem which has eroded while the rest of the stem body remains in relatively good condition. The present application discloses a novel system allowing for quick replacement of the stem tip and an efficient method for doing so.