Abstract: A method for determining a recovery factor of a deep coal bed methane (CBM) well includes steps of: (1) collecting an original formation pressure and pressure-volume-temperature (PVT) experimental data of the CBM well, and establishing a relationship table between pressure and deviation factor; (2) obtaining isothermal adsorption experimental data, an original adsorbed gas content and an original free gas content for the deep coal rock; (3) according to the isothermal adsorption experimental data, determining Langmuir's pressure and Langmuir's volume; (4) determining an abandoned formation pressure in CBM well exploitation; (5) obtaining a deviation factor at the original formation pressure and a deviation factor at the abandoned formation pressure; and (6) according to the original formation pressure, the original adsorbed gas content, the original free gas content, the Langmuir's pressure, the abandoned formation pressure, the above deviation factors, the recovery factor of the CBM well is calculated.

Abstract: A method for determining production shares of free gas and adsorbed gas in deep coalbed methane well mining includes steps of: collecting an original formation pressure and PVT sampling experimental analysis data of a coalbed methane well to obtain deviation factors; collecting isothermal adsorption experimental data as well as adsorbed gas content and free gas content under the original formation pressure and the temperature conditions; determining a Langmuir pressure and a Langmuir volume based on the isothermal adsorption experimental data; determining daily production of the free gas and the adsorbed gas, determining a coalbed methane recovery percent, and determining production shares of the free gas and the adsorbed gas under any formation pressure; and obtaining the production shares of the free gas and the adsorbed gas under different recovery percent. The method is simple, easy to understand and implement.

Abstract: A method for determining productivity of deep coalbed methane well considering impacts of fracturing fluids and produced water includes steps of: based on coalbed methane PVT experimental data, determining a relationship table between pressure and deviation factor, and determining process parameter; recording daily gas production rates, bottomhole flow pressures, cumulative gas productions, and cumulative water production; determining formation pressures based on a coalbed methane material balance equation considering the impacts of the fracturing fluids and the produced water; according to the formation pressures, the bottomhole flow pressures and the production rates, determining coefficients in a deliverability equation for the coalbed methane well, thereby determining the deliverability equation; putting the formation pressure and the bottomhole flow pressures into the deliverability equation and solving for the productivity of the coalbed methane well.

Abstract: Provided are a communication method and apparatus for an external device, allocating an IP address to the external device to access the base station, wherein the external device is connected to the base station through an Ethernet interface of a destination device; searching corresponding relations between internal IP addresses and Ethernet interfaces for the Ethernet interface corresponding to the allocated internal IP address; determining destination device information corresponding to the destination device to which the found Ethernet interface belongs; searching model data of all external devices for model data comprising the destination device information, and establishing a corresponding relation between the found model data and the allocated internal IP address, wherein the model data is configured to identify the external device; and communicating with the external device identified by the model data through the internal IP address corresponding to the model data.

Abstract: A method for determining adsorbed gas content during a production process of a deep coalbed methane well, includes steps of: collecting an original formation pressure, PVT experimental analysis data, a Langmuir pressure, an adsorbed gas content in the reserves under the original formation pressure conditions, a free gas content in the reserves under the original formation pressure conditions, and a coalbed methane well productivity equation obtained based on historical production test data; establishing a functional relationship expression between the deviation factor and the formation pressure; obtaining a coalbed methane well production and a bottom hole flow pressure at a preset production time; determining a formation pressure at the preset production time; and determining a deviation factor under an original formation pressure condition; utilizing a model to determine the adsorbed gas content pera in the coal bed methane production at the corresponding production time.

Abstract: A method for determining a productivity of a coalbed methane well without shutting down the well includes steps of: obtaining coalbed methane basic data; based on PVT experimental data, determining a relationship table between a pressure and a coalbed methane deviation factor, and a relationship table between the pressure and a pseudo-pressure; recording daily gas production rates, bottomhole flow pressures, and cumulative gas productions at each stabilized flow pressure test moment in at least three different production stages; determining formation pressures corresponding to each stabilized flow pressure test moment based on a material balance equation; according to the formation pressures, the bottomhole flow pressures and the production rates, determining coefficients in a deliverability equation of the coalbed methane well for determining the deliverability equation; substituting the formation pressures and the bottomhole flow pressures into the deliverability equation for obtaining corresponding product

Abstract: A star rating management method for deployment and implementation of gas field development wells first establishes the expression for estimating the gas well initial production rate and the dimensionless production curve; then determines the annual production of the new well for every year during the evaluation period and determines the internal rate of return of the new gas well. If the internal rate of return fails to meet the requirement, the deployment location and construction technology of the new well are re-optimized. Corresponding stars rating are determined according to the internal rate of return of the gas wells. The new well is drilled according to the deployment location that can meet the economic benefit requirements. After the gas well is drilled, a more detailed fracturing design is carried out, and the internal rate of return of the gas well and the star rating of development benefit are redetermined.

Abstract: A method for evaluating a gas well productivity with eliminating an influence of liquid loading includes steps of: collecting basic data of a liquid loading gas well; according to a relative density of natural gas, a formation depth, and a casing pressure during a productivity test, determining a pressure generated by a static gas column in an annular space between a casing and a tubing from a well head to a bottomhole of the gas well, and obtaining a bottomhole pressure without liquid loading; according to a pseudo-pressure of a formation pore pressure, pseudo-pressures of the bottomhole pressure respectively under the conditions of liquid loading and no liquid loading, and a production rate under the condition of liquid loading, determining a production rate without liquid loading, and determining an absolute open flow rate with eliminating the influence of liquid loading.

Abstract: A method for evaluating a gas well productivity with eliminating an influence of liquid loading includes steps of: collecting basic data of a liquid loading gas well; according to a relative density of natural gas, a formation depth, and a casing pressure during a productivity test, determining a pressure generated by a static gas column in an annular space between a casing and a tubing from a well head to a bottomhole of the gas well, and obtaining a bottomhole pressure under a condition of no liquid loading; according to a pseudo-pressure of a formation pore pressure, pseudo-pressures of the bottomhole pressure respectively under the conditions of liquid loading and no liquid loading, and a production rate under the condition of liquid loading, determining a production rate under the condition of no liquid loading, and determining an absolute open flow rate with eliminating the influence of liquid loading.