Abstract: A method in a computer system expands an initial set of trend data values by generating an interpolating the initial set of trend data values. An input data stream of the initial set of trend data values is received. Each initial trend data value is divided into two extrapolated values. A first extrapolated value is less than its corresponding initial trend data value. A second extrapolated value is greater than its corresponding initial trend data value. A time period of each initial trend data value is divided in half. The first extrapolated value is associated with a first half of the time period. The second extrapolated value is associated with a second half of the time period. An output data stream is a series of the first and second extrapolated values each over half of the time period to create an expanded set of trend values.

Abstract: Methods and apparatuses are disclosed for optimizing oil and gas wells. Some embodiments may include optimizing a gas well based upon continuous measurements of the well's operating parameters, such as casing pressure draw down and/or line pressure surges. These continuous measurements of the well's parameters may be utilized to derive an empirical model of the well's behavior that is more accurate than conventional approaches with respect to the various stages of well production. In other words, by measuring the well's operating parameters continuously and measuring certain well parameters (like casing pressure draw down and/or surges in line pressure from opening the well), the empirical model derived therefrom may provide more accurate control of turn on criteria of the well than conventional approaches, such as during the mature production stage of production of the well.

Abstract: A system for communication in an oil and gas well, the system including a controller, a first universal wireless adapter (UWA) wirelessly coupled to the controller, where the UWA is coupled to a first field device, a second UWA wirelessly coupled to the controller, where the UWA is coupled to a second field device, where the controller passes a control token among the first and second UWAs based upon communication traffic between the first and second UWA and the first and second field devices respectively. In some embodiments, this control token may be passed between the first and second UWAs depending upon communications between the respective UWAs and their field devices. For example, in the event that communication traffic is greater between the first UWA and the first field device, then the control token is passed to the first UWA.

Abstract: A system for communication in an oil and gas well, the system including a controller, a first universal wireless adapter (UWA) wirelessly coupled to the controller, where the UWA is coupled to a first field device, a second UWA wirelessly coupled to the controller, where the UWA is coupled to a second field device, where the controller passes a control token among the first and second UWAs based upon communication traffic between the first and second UWA and the first and second field devices respectively. In some embodiments, this control token may be passed between the first and second UWAs depending upon communications between the respective UWAs and their field devices. For example, in the event that communication traffic is greater between the first UWA and the first field device, then the control token is passed to the first UWA.

Abstract: Methods and apparatuses are disclosed for optimizing oil and gas wells. Some embodiments may include optimizing a gas well based upon continuous measurements of the well's operating parameters, such as casing pressure draw down and/or line pressure surges. These continuous measurements of the well's parameters may be utilized to derive an empirical model of the well's behavior that is more accurate than conventional approaches with respect to the various stages of well production. In other words, by measuring the well's operating parameters continuously and measuring certain well parameters (like casing pressure draw down and/or surges in line pressure from opening the well), the empirical model derived therefrom may provide more accurate control of turn on criteria of the well than conventional approaches, such as during the mature production stage of production of the well.

Abstract: Methods and apparatuses are disclosed for measuring and controlling liquid levels in a well. The apparatus may include a plurality of sensors, the plurality of sensors comprising: a first sensor coupled to the well, the first sensor configured to measure a casing pressure, a second sensor coupled to the well, the second sensor configured to measure a tubing pressure, and a third sensor coupled to a motor that is further coupled to the well, the third sensor configured to measure at least one characteristic of the motor, and a processor coupled to the plurality of sensors, wherein the processor calculates a level of liquid in the well based upon measurements of at least two of the plurality of sensors.

Abstract: A method and system to pulse at least one solenoid valve to regulate the volume of instrument air or other gas (e.g. nitrogen or natural gas) to the supply side or from the discharge side of a diaphragm actuator. The diaphragm actuator operates a primary variable flow/choke control valve in response to process control signals.

Abstract: This system connects groups of end-devices at two or more automated oil or gas production wellheads or groups of end-devices at two or more associated wellhead facilities so that such associated end devices may be wirelessly monitored and measured during wellhead production, and then wirelessly controlled by one or more master remote terminal/telemetry unit MRTU. Each MRTU is in turn in communication with and controlled by a host computer system. Such measurement and control of the end devices is accomplished through slave remote terminal/telemetry units SRTUs which are connected to and capable of communications with associated end-devices. Each SRTU is in turn connected to one or more local area network LAN communication system, each of which LAN is in turn connected, by hard wire or wirelessly, to a wide area network WAN transmitter. Each WAN is in wireless communication with a host computer.

Abstract: In a coal seam gas well, variable speed submersible pumps are used to remove the water from the well bore in order to release the methane gas absorbed in the coal bed and in the water. To optimize gas production, the liquid must be removed at an optimum rate, while still maintaining a certain minimum fluid level within the bore. To achieve this optimum control of the pump, analytical data of liquid flow rate, liquid level trend within the bore, and operating data of the submersible pump is used to control the liquid pump speed and the on-off timing of the liquid pump. High-resolution trending and event-log data provide artificial intelligence control to improve recovery of liquids from a coal seam gas well reservoir, and to reduce the operating cost.

Abstract: This system and Method serve as both a raw data logger for well operation analysis and a well event logger for well performance analysis. An improved methodology of remote event and process variable logging and data retention designed specifically to address the needs of intermittently flowing gas wells is useful for eliminating gas slippage associated with intermittent or erratic gas flow conditions, eliminating measurement errors, and lowering operating costs. The well data can be scanned in seconds for its current flow situation, and as a set of specific conditions are met, a built-in control program reacts to those conditions by shutting down the well until certain pressure criteria are met to allow the well to flow again. To maintain measurement integrity, precise event logging of the valve positions to indicate the actual flowing period are included in the flow integration.

Abstract: A method and related system are disclosed for combining two fluids in correct proportions. The flow rates of the two fluids are measured and the volume proportion of the first fluid to the second fluid is determined from these measurements. The flow rate of the first fluid is then continuously adjusted to bring the proportion of the fluids to and be maintained at a predetermined value. In one embodiment of the present invention, the flow of an inert gas and the flow of a hydrocarbon gas are measured and adjusted prior to combining and injection into a wellbore. A microprocessor is utilized to calculate the proportion of the fluids from the measurements of flow and then to automatically change the position of the valve to adjust the flow rate of the inert gas.