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Chris Carpenter - One of the best experts on this subject based on the ideXlab platform.

  • Measured Plunger-Fall Velocity Used To Calibrate New Fall-Velocity Model
    Journal of Petroleum Technology, 2013
    Co-Authors: Chris Carpenter
    Abstract:

    This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 164495, ’Measured Plunger-Fall Velocity Used To Calibrate New Fall-Velocity Model,’ by O.L. Rowlan and J. McCoy, Echometer Company; J. Lea, PLTech; and R. Nadkrynechny and C. Cepuch, T-RAM Canada, prepared for the 2013 SPE Production and Operations Symposium, Oklahoma City, Oklahoma, USA, 23-26 March. The paper has not been peer reviewed. Fall velocities for various plungers have been measured under many different field and simulator conditions. A new theoretical plunger-fall-velocity model uses a specific Pressure and temperature for calibration. The model can then be used to calculate fall velocity at other conditions for the same plunger or can be used to show how changing a feature such as plunger weight can affect fall velocity. Introduction Conventional plunger lift is a low-cost method for lifting liquids (water, condensate, or oil) from gas and oil wells.  Lifting liquids from the well is achieved by closing a surface valve to store energy in the well during a shut-in time period, which is followed by opening the surface valve for a time period so liquids are unloaded as gas flows to the surface. During shut-in, the gas flow is stopped when the controller closes the surface motor valve. The plunger leaves the lubricator to begin its fall from the surface because of a tubing-Pressure increase that is caused by closing the motor valve or begun when the plunger is released from a catcher. The plunger falls through gas until entering the accumulated liquid at the bottom of the tubing. Once the plunger is on bottom and sufficient unloading energy is stored, the controller opens the surface valve into the lower-Pressure Flowline. High-Pressure gas in the tubing above the liquid column flows down the Flowline, and the high-Pressure gas in the casing begins to decrease by expanding to fill the tubing, displacing the plunger and most of the liquid above the plunger to the surface. This plunger-operation cycle is repeated continually to produce the well. An operator can produce from the well efficiently if the plunger’s fall rate and location and the time taken to fall to the liquid and bottom of the tubing are known accurately. The distance to the plunger and the rate of fall can be determined by examining the acoustic signal created by a falling plunger. The acoustic pulse generated at the tubing-collar recess travels through the gas to the surface to be detected by a microphone, and the change in Pressure can be detected by a tubing Pressure transducer. These acoustic pulses are normally detected as a plunger falls down the relatively dry tubing interior above the gaseous liquid column at the bottom of the well. Processing this acoustic signal allows the depth and fall velocity of the falling plunger to be determined. Fig. 1 shows the plunger-fall velocity decreasing smoothly as a function of time. Although there seems to be some scatter of velocities on the plunger-velocity trace, note that the left vertical scale is amplified and that the general trend of the velocity is to consistently decrease as time (plunger depth) increases.

Augusto L. Podio - One of the best experts on this subject based on the ideXlab platform.

  • Determining How Different Plunger Manufacture Features Affect Plunger Fall Velocity
    All Days, 2003
    Co-Authors: O.l. Rowlan, J.n. Mccoy, Augusto L. Podio
    Abstract:

    Abstract Tracking the fall of the plunger down the tubing can be used to optimize the operation of plunger lifted wells. Acoustic fluid level instruments can be used on plunger lifted wells to acquire a series of plunger/fluid level soundings and/or to record the acoustic signal produced as the plunger falls down the tubing. Five different data acquisition and analysis methods can be used to monitor the position of the plunger, as the plunger falls down the tubing during the controller's shut-in time period. The acquired data is used to determine thefall velocity of the plungerdepth to the plunger andtime for the plunger to fall to fluid. Results acquired from field case studies from 15 sessions at various wells are used to correlate the various construction features of different types of plungers with their fall velocity. Some construction features cause a plunger to fall rapidly through the tubing, while other features cause the plunger to have a slow fall velocity. By accurately measuring the plunger fall velocity, the proper shut-in time for the plunger lift installation can be determined. The plunger trace measurements will ensure that the plunger has reached the fluid at the bottom of the tubing by the end of the shut-in period. Setting the well's controller to have the shortest possible shut-in time period to allow the plunger to fall to bottom can maximize oil and gas production from plunger lift installations. Introduction Some wells produce gas with a small amount of liquid. The gas is usually produced only up the tubing and is normally not produced up the casing annulus. The produced gas carries the liquid into the tubing and the produced liquid generally accumulate in the tubing. If the gas velocity up the tubing is above the Turner critical velocity, then the liquid will be carried with the gas to the surface. If the gas velocity up the tubing is below the critical velocity, then the produced liquid will accumulate in bottom of the tubing1. Gas and liquid flow from the formation will decrease or even stop, if enough liquid is allowed to accumulate in the bottom of the well. BackPressure on the formation increases as the height of the accumulated liquid increases and eventually flow from the formation will cease when the backPressure on the formation is equal to the static Pressure of the reservoir. Artificial lift methods to produce the accumulated liquid vary. Sometimes pumping units are used dewater gas wells by pumping the liquid to the surface, but plunger lift is the technique that is most frequently used to lift the liquid accumulated at the bottom of the tubing of low productivity gas wells to the surface. Plunger lift is a low cost method for lifting liquids (water, condensate and/or oil) from gas and oil wells. This system reduces the cost of operating a well compared to other artificial lift methods, because the formation Pressure supplies the energy used to lift the liquids. During plunger lift operations, repeated cycles of surface gas flow and surface gas shut-in occurs. During shut-in the gas flow down the Flowline is stopped when the surface control valve is closed. This allows the plunger to fall down to the bottom of the tubing. After a pre-determined amount of time the surface flow valve opens and the tubing is connected to the low-Pressure Flowline. This reduces the Pressure in the tubing above the liquid column and the Pressure below the plunger lifts the plunger and most of the liquid above the plunger to the surface. During this process the bottomhole Pressure is reduced and this allows additional gas to flow from the formation and casing annulus and be produced at the surface. The plunger operation cycle is continually repeated to produce the well. An operator can produce the well more efficiently if the plunger fall rate, plunger location, and time the plunger takes to fall to the liquid and bottom of tubing are determined. Five different data acquisition and analysis methods can be used to monitor the position of the plunger, as the plunger falls down the tubing during the shut-in time period. An acoustic liquid level instrument is used to determine the distance from the surface to the top of the plunger during the shut-in portion of plunger lift operational cycle. The distance to the plunger and the rate of fall can be measured when the plunger is above the liquid. When the plunger enters the liquid, the acoustic pulse reflects from the top of the liquid so that the distance to the liquid level is measured. This paper discusses the procedures used to apply five different data acquisition and analysis methods to track the fall of the plunger, and gives examples of the data collected by each method.

O.l. Rowlan - One of the best experts on this subject based on the ideXlab platform.

  • Determining How Different Plunger Manufacture Features Affect Plunger Fall Velocity
    All Days, 2003
    Co-Authors: O.l. Rowlan, J.n. Mccoy, Augusto L. Podio
    Abstract:

    Abstract Tracking the fall of the plunger down the tubing can be used to optimize the operation of plunger lifted wells. Acoustic fluid level instruments can be used on plunger lifted wells to acquire a series of plunger/fluid level soundings and/or to record the acoustic signal produced as the plunger falls down the tubing. Five different data acquisition and analysis methods can be used to monitor the position of the plunger, as the plunger falls down the tubing during the controller's shut-in time period. The acquired data is used to determine thefall velocity of the plungerdepth to the plunger andtime for the plunger to fall to fluid. Results acquired from field case studies from 15 sessions at various wells are used to correlate the various construction features of different types of plungers with their fall velocity. Some construction features cause a plunger to fall rapidly through the tubing, while other features cause the plunger to have a slow fall velocity. By accurately measuring the plunger fall velocity, the proper shut-in time for the plunger lift installation can be determined. The plunger trace measurements will ensure that the plunger has reached the fluid at the bottom of the tubing by the end of the shut-in period. Setting the well's controller to have the shortest possible shut-in time period to allow the plunger to fall to bottom can maximize oil and gas production from plunger lift installations. Introduction Some wells produce gas with a small amount of liquid. The gas is usually produced only up the tubing and is normally not produced up the casing annulus. The produced gas carries the liquid into the tubing and the produced liquid generally accumulate in the tubing. If the gas velocity up the tubing is above the Turner critical velocity, then the liquid will be carried with the gas to the surface. If the gas velocity up the tubing is below the critical velocity, then the produced liquid will accumulate in bottom of the tubing1. Gas and liquid flow from the formation will decrease or even stop, if enough liquid is allowed to accumulate in the bottom of the well. BackPressure on the formation increases as the height of the accumulated liquid increases and eventually flow from the formation will cease when the backPressure on the formation is equal to the static Pressure of the reservoir. Artificial lift methods to produce the accumulated liquid vary. Sometimes pumping units are used dewater gas wells by pumping the liquid to the surface, but plunger lift is the technique that is most frequently used to lift the liquid accumulated at the bottom of the tubing of low productivity gas wells to the surface. Plunger lift is a low cost method for lifting liquids (water, condensate and/or oil) from gas and oil wells. This system reduces the cost of operating a well compared to other artificial lift methods, because the formation Pressure supplies the energy used to lift the liquids. During plunger lift operations, repeated cycles of surface gas flow and surface gas shut-in occurs. During shut-in the gas flow down the Flowline is stopped when the surface control valve is closed. This allows the plunger to fall down to the bottom of the tubing. After a pre-determined amount of time the surface flow valve opens and the tubing is connected to the low-Pressure Flowline. This reduces the Pressure in the tubing above the liquid column and the Pressure below the plunger lifts the plunger and most of the liquid above the plunger to the surface. During this process the bottomhole Pressure is reduced and this allows additional gas to flow from the formation and casing annulus and be produced at the surface. The plunger operation cycle is continually repeated to produce the well. An operator can produce the well more efficiently if the plunger fall rate, plunger location, and time the plunger takes to fall to the liquid and bottom of tubing are determined. Five different data acquisition and analysis methods can be used to monitor the position of the plunger, as the plunger falls down the tubing during the shut-in time period. An acoustic liquid level instrument is used to determine the distance from the surface to the top of the plunger during the shut-in portion of plunger lift operational cycle. The distance to the plunger and the rate of fall can be measured when the plunger is above the liquid. When the plunger enters the liquid, the acoustic pulse reflects from the top of the liquid so that the distance to the liquid level is measured. This paper discusses the procedures used to apply five different data acquisition and analysis methods to track the fall of the plunger, and gives examples of the data collected by each method.

J.n. Mccoy - One of the best experts on this subject based on the ideXlab platform.

  • Determining How Different Plunger Manufacture Features Affect Plunger Fall Velocity
    All Days, 2003
    Co-Authors: O.l. Rowlan, J.n. Mccoy, Augusto L. Podio
    Abstract:

    Abstract Tracking the fall of the plunger down the tubing can be used to optimize the operation of plunger lifted wells. Acoustic fluid level instruments can be used on plunger lifted wells to acquire a series of plunger/fluid level soundings and/or to record the acoustic signal produced as the plunger falls down the tubing. Five different data acquisition and analysis methods can be used to monitor the position of the plunger, as the plunger falls down the tubing during the controller's shut-in time period. The acquired data is used to determine thefall velocity of the plungerdepth to the plunger andtime for the plunger to fall to fluid. Results acquired from field case studies from 15 sessions at various wells are used to correlate the various construction features of different types of plungers with their fall velocity. Some construction features cause a plunger to fall rapidly through the tubing, while other features cause the plunger to have a slow fall velocity. By accurately measuring the plunger fall velocity, the proper shut-in time for the plunger lift installation can be determined. The plunger trace measurements will ensure that the plunger has reached the fluid at the bottom of the tubing by the end of the shut-in period. Setting the well's controller to have the shortest possible shut-in time period to allow the plunger to fall to bottom can maximize oil and gas production from plunger lift installations. Introduction Some wells produce gas with a small amount of liquid. The gas is usually produced only up the tubing and is normally not produced up the casing annulus. The produced gas carries the liquid into the tubing and the produced liquid generally accumulate in the tubing. If the gas velocity up the tubing is above the Turner critical velocity, then the liquid will be carried with the gas to the surface. If the gas velocity up the tubing is below the critical velocity, then the produced liquid will accumulate in bottom of the tubing1. Gas and liquid flow from the formation will decrease or even stop, if enough liquid is allowed to accumulate in the bottom of the well. BackPressure on the formation increases as the height of the accumulated liquid increases and eventually flow from the formation will cease when the backPressure on the formation is equal to the static Pressure of the reservoir. Artificial lift methods to produce the accumulated liquid vary. Sometimes pumping units are used dewater gas wells by pumping the liquid to the surface, but plunger lift is the technique that is most frequently used to lift the liquid accumulated at the bottom of the tubing of low productivity gas wells to the surface. Plunger lift is a low cost method for lifting liquids (water, condensate and/or oil) from gas and oil wells. This system reduces the cost of operating a well compared to other artificial lift methods, because the formation Pressure supplies the energy used to lift the liquids. During plunger lift operations, repeated cycles of surface gas flow and surface gas shut-in occurs. During shut-in the gas flow down the Flowline is stopped when the surface control valve is closed. This allows the plunger to fall down to the bottom of the tubing. After a pre-determined amount of time the surface flow valve opens and the tubing is connected to the low-Pressure Flowline. This reduces the Pressure in the tubing above the liquid column and the Pressure below the plunger lifts the plunger and most of the liquid above the plunger to the surface. During this process the bottomhole Pressure is reduced and this allows additional gas to flow from the formation and casing annulus and be produced at the surface. The plunger operation cycle is continually repeated to produce the well. An operator can produce the well more efficiently if the plunger fall rate, plunger location, and time the plunger takes to fall to the liquid and bottom of tubing are determined. Five different data acquisition and analysis methods can be used to monitor the position of the plunger, as the plunger falls down the tubing during the shut-in time period. An acoustic liquid level instrument is used to determine the distance from the surface to the top of the plunger during the shut-in portion of plunger lift operational cycle. The distance to the plunger and the rate of fall can be measured when the plunger is above the liquid. When the plunger enters the liquid, the acoustic pulse reflects from the top of the liquid so that the distance to the liquid level is measured. This paper discusses the procedures used to apply five different data acquisition and analysis methods to track the fall of the plunger, and gives examples of the data collected by each method.

Esam I. Jassim - One of the best experts on this subject based on the ideXlab platform.

  • Modeling of Hydrate Deposition in Loading and Offloading Flowlines of Marine CNG Systems
    International Journal of Literature and Arts, 2015
    Co-Authors: Esam I. Jassim
    Abstract:

    The main aim of this paper is to demonstrate the prediction of the model capability of predicting the nucleation process, the growth rate, and the deposition potential of hydrate particles in gas Flowlines. The primary objective of the research is to predict the risk hazards involved in the marine transportation of compressed natural gas. However the proposed model can be equally used for other applications including production and transportation of natural gas in any high Pressure Flowline. The proposed model employs the following three main components to approach the problem: computational fluid dynamics (CFD) technique is used to configure the flow field; the nucleation model is developed and incorporated in the simulation to predict the incipient hydrate particles size and growth rate; and the deposition of the gas/particle flow is proposed using the concept of the particle deposition velocity. These components are integrated in comprehended model to locate the hydrate deposition in natural gas Flowlines. The present research is prepared to foresee the hydrate deposition location that could occur in a real application in Compressed Natural Gas loading and offloading. A pipeline with 120 m length and different sizes carried a natural gas is taken in the study. The location of hydrate deposition formed as a result of restriction is determined based on the procedure mentioned earlier and the effect of water content and downstream Pressure is studied. The critical flow speed that prevents hydrate to accumulate in the certain pipe length is also addressed.