Reservoir fluid study, 258 results

We will see in this chapter that field data can also be used to determine some properties of the reservoir fluid—in particular, bubble-point pressure and solution gas-oil ratio at the bubble point. These two properties are insufficient to permit prediction of reservoir behavior, but they can be used to check the results of reservoir fluid studies or correlations. 

The following physical properties can be determined from the results of a black oil reservoir fluid study bubble-point pressure, formation volume factor of oil, solution gas-oil ratio, total formation volume factor, coefficient of isothermal compressibility of oil, and oil viscosity,... 

The results of these procedures are called a reservoir fluid study. Often the term PVT study is used. 

First, we will examine the five major tests performed during a reservoir fluid study. Later we will see how to convert the results into fluid properties of interest to the petroleum engineer. 

The results of a flash vaporization are given on page 4 of the example black oil reservoir fluid study, Table 10-1. 

All the fluid properties required for a reservoir study using material balance equations can be calculated from the results of a reservoir fluid study.3... 

There are a number of special symbols which are used only in referring to the results of a black oil reservoir fluid study. These symbols are defined in Table 10-3. The subscripts o and g refer to liquid and gas, as always. The subscripts F, D, and S refer to flash vaporization, differential vaporization, and separator test, respectively. The subscript b is added to indicate that the quantity is measured at the bubble point. 

When a reservoir fluid study is unavailable, the engineer must rely on correlations to estimate values of the physical properties of interest. I have compared most of the published fluid property correlations with the results of hundreds of reservoir fluid studies. The best available correlations are given in this chapter. 

Hyaluronan occurs in virtually all vertebrate tissues and fluids, but skin is the largest reservoir of body HA, containing more than 50% of the total. Earlier studies on the distribution of HA in skin, using histolocalization techniques, seriously underestimated HA levels. Formalin is an aqueous fixative, and much of the soluble tissue HA is eluted by this procedure. The length of time tissue in the formalin is a variable that may explain the conflicting results that are often encountered. Acidification and addition of alcohol to the fixative causes the HA to become more avidly fixed, so that subsequent aqueous steps are unable to elute HA out of the tissue.18... 

In order to test the functionality and reservoir properties of the new tethered lipid bilayers, the ion carrier valinomycin was used to study the selective transport of potassium ions. The data, shown in Table 1, confirmed the formation of a fluid and insulating tBLM. The addition of 0.1 M potassium ions resulted in a drop in resistance of up to three orders in magnitude corresponding well to literature values [13],... 

The chemistry of and physical mechanisms controlling the recovery of petroleum are better understood now than at any previous time yet, an extremely large amount of work remains before recoveries can be predicted with certainty. Part of this uncertainty arises from the undetermined variables of the heterogeneous reservoir matrix from which oil is produced and partly from simply not understanding the total interrelationship of the forces acting on the fluids in the reservoir. New chemical techniques and ideas for measurement undoubtedly will develop from the kinds of studies reported in this publication the result will be the achievement of a more efficient recovery of our petroleum resources. 

The fluctuation in gas rate is also associated with fine flow induced by great change in PEL. Coal from this well presents in block, with some in powder (Fig. 2(b)), which is controlled by faults within the study area. The extreme change in PEL leads to quick pressure drop, gas desorption within reservoir near wellbore, and thus the high gas rate in a short time. However, quick and fluctuate drainage system can contribute to coal fine concentration increase in fluid, fine accumulation in pore and finally a dramatic gas rate decrease after present fine production, gas rate will increase in a short time as a result of the better permeability and conductivity. 

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