Patent Application
20250163792
Not Applicable.
This invention relates generally to a surface well testing system used to measure oil and gas well production rates at the wellhead or downstream of the production manifold.
A surface well testing system is typically used to measure oil and gas well producing rates for oil, gas, and water at the wellhead or downstream of the production manifold. A conventional well test separator uses a horizontal three-phase separator to separate oil, gas, and water. Individual flow meters then measure the gas, oil, and water producing rate from the well. The measurement uncertainty is typically about 5% for each of the phases, namely gas, oil, and water. It requires a well testing crew, which must work 24 hour shifts to operate and conduct the well testing task. It also requires a long rig-up and rig-down time. Thus, the conventional well test separator has low efficiency and high costs.
Multiphase flow meters (MPFM) are a new technology developed in the past 25 years. It is installed at the wellhead for real-time well production monitoring or measurements. Some of the MPFM technologies perform well for oil wells but perform poorly for wet gas wells. It usually has high measurement uncertainty, from 5-20%, and thus is not recommended for highly accurate well testing operations.
Based on the foregoing, it is desirable to provide a compact well testing system that serves as a multiphases flow meter that incorporates a compact two-phase cyclone separator for accurate measurements.
In general, in a first aspect, the invention relates to a compact well testing system comprising a two-phase cyclone separator capable of separating a gas-liquid-sand flow into a gas stream, a liquid stream, and a solid stream; a gas mass flow meter capable of measuring the gas stream; a liquid mass flow meter capable of measuring the liquid stream; and a sand measurer capable of measuring the solid stream.
The two-phase cyclone separator may comprise a solid separation cyclone and a gas cyclone. The compact well testing system may further comprise a microwave water cut meter, a gas control valve, and/or a liquid control valve.
In a second aspect, the invention relates to a method of measuring oil and gas well producing rates, the method comprising: separating a gas-liquid-sand flow into a gas stream, a liquid stream, and a solid stream via a solid separation cyclone and a gas-liquid two-phase cyclone separator; measuring the gas stream via a gas mass flow meter; measuring the liquid stream via a liquid mass flow meter; and measuring the solid stream via a solid concentration measurement device.
Separating the gas-liquid-sand flow into the gas stream, the liquid stream, and the solid stream may comprise: allowing the gas-liquid-sand flow to enter a solid separation cyclone; generating strong centrifugal force with the solid separation cyclone to separate solid particles into an annulus through an tangential opening slot of the solid cyclone wall; collecting the solid particles at a bottom of the solid separation cyclone; draining the solid particles to produce the solid stream; allowing a gas-liquid phase from the solid separation cyclone to enter a vertical churn flow coalescer before passing through a horizontal inlet section to enter a gas-liquid separation chamber of a gas-liquid cyclone; allowing the gas-liquid phase to enter a demisting cyclone of the gas-liquid cyclone; generating strong centrifugal force with the demisting cyclone to separate liquid droplets into an annulus through an tangential opening slot of the demisting cyclone wall; draining the accumulated liquid in the annulus into the gas-liquid separation chamber; allowing the liquid in the gas-liquid separation chamber to exit the two-phase cyclone separator via a liquid stream outlet to produce the liquid stream; and allowing gas to exit the two-phase separator via a gas stream outlet located at a top of the liquid droplet separation cyclone to produce the gas stream.
The method may further comprise passing the liquid stream through a microwave water cut meter after measuring the liquid stream via the liquid mass flow meter.
The method may further comprise rejoining the gas stream, the liquid stream, and the solid stream into a gas-liquid-sand output.
Other advantages and features will be apparent from the following description and from the claims.
The devices and methods discussed herein are merely illustrative of specific manners in which to make and use this invention and are not to be interpreted as limiting in scope.
While the devices and methods have been described with a certain degree of particularity, it is to be noted that many modifications may be made in the details of the construction and the arrangement of the devices and components without departing from the spirit and scope of this disclosure. It is understood that the devices and methods are not limited to the embodiments set forth herein for purposes of exemplification.
In general, in a first aspect, the invention relates to a compact well testing system. As seen in
A flow computer may be used to collect data from the gas, liquid, and sand measurements to compute the volumetric rates based on the fluids properties and operating pressure and temperature.
Gas-liquid phases from the solid separation cyclone 2 may enter the vertical churn flow coalescer 15, in which the flow velocity may be drastically reduced to promote droplets and bubbles coalescence.
A horizontal inlet section may comprise a 90-degree tee 16 in conjunction with the gas-liquid cyclone 3. A flow divert plate 17 may be installed internally to direct the flow downward and tangentially to the gas-liquid cyclone 3.
The gas-liquid cyclone 3 may comprise a gas-liquid separation chamber 18 in the middle, a droplet separation cyclone 19 in the upper part supported by a support sitting ring 20, and a secondary sand accumulation chamber 21 in the bottom. The liquid droplet separation cyclone 19 may separate liquid droplets from the gas stream, allowing the liquid to exit the liquid droplet separation cyclone 19 via a pipe opening slot 22 and accumulate in the annulus before draining to the bottom of the gas-liquid separation chamber 18 via tube 23.
Liquid may exit the system via a liquid stream outlet 24 located at the bottom of the gas-liquid separation chamber 18, gas may exit the system via a gas stream outlet 25 located at the top of the liquid droplet separation cyclone 19, and solids may exit the system via the solid outlet 13 located at the bottom of the solid separation cyclone 2 and/or the bottom of the gas-liquid cyclone 3.
The compact well testing system may be installed at the wellhead or downstream of the production manifold. As seen in
The system was constructed and tested by a third-party wet gas flow loop using natural gas, condensate oil, and saline water. The test conditions included a pressure of 800 psi, a gas flow rate ranging from 5 to 25 MMscfd, a liquid flow rate ranging from 500 to 4,500 bbl/s, and a water cut range of 0 to 100%. The results, shown in
Whereas, the devices and methods have been described in relation to the drawings and claims, it should be understood that other and further modifications, apart from those shown or suggested herein, may be made within the spirit and scope of this invention.
