Keywords future well performance, inflow performance relationship, layers flow in the reservoir are classified into either theoretical or empirical approaches. Qasem () presented a detailed study of IPR for naturally fractured reservoirs. In , Vogel proposed an empirical inflow performance relationship (IPR) for theoretical calculations that showed a curved relationship between flow rate. Inflow Performance Relationship Prediction predict the future IPR curve for the well as a result of change in Kro/Boμo.
They showed that Fetkovich Equation can be a good representation of the deliverability equation especially in the transition zone where the Pwf is slightly lower than the Pb and the shape of Krg is not increasing sharply with increase in gas saturation.
The nk values range from 0. InAvery and Evans [ 22 D. IPR curves were also used during enhanced oil recovery process where Yeu et al.
Oil well performance
After emerging of the multi-lateral technology, Guo et al. These are few of the many applications of IPR in oil industry.
Most of the IPR correlations suffer from common limitations that they are not explicitly function of the different reservoir rock and fluid properties that vary from one reservoir to another or its difficulty to be applied. This will affect the accuracy of the correlations especially if the reservoir properties of the well under study are completely different from the properties used in generating these correlations.
In this work, a single well 3D radial reservoir model with solution gas-drive as the main driving mechanism was built and reservoir simulation was used to generate different IPRs by changing the reservoir rock and fluid properties.
The most sensitive reservoir rock and fluid properties were selected to generate the new IPR correlation.
Oil well performance -
This new correlation is based on generating combination of the selected reservoir rock and fluid properties and run the simulation models to generate different IPR curves. Then, the non-parametric regression technique was used to generate the new IPR correlation that is explicitly function of the reservoir rock and fluid properties that highly affect the IPR curve. The outline of the paper is as follows. Firstly, we presented the assumptions we used in generating the single well reservoir simulation model.
Secondly, we studied the sensitivity of the IPR towards different rock and fluid parameters to choose the highly sensitive parameters to be used in the IPR correlation. Thirdly, we presented the nonlinear and non-parametric regression techniques we used to develop the IPR correlation that is explicitly function of reservoir rock and fluid properties. Finally, we presented the validation of the new correlation based on different synthetic and field cases.
Once a and b have been determined, the flow rate at any other flowing wellbore pressure can be obtained by solving Other methods There are several other two-phase IPR methods available in the literature.
Analytical Development Of Vogel-Type Inflow Performance Relationships - OnePetro
Gallice and Wiggins  provide details on the application of several of these methods and compare and discuss their use in estimating oilwell performance with advantages and disadvantages. Single- and two-phase flow In certain circumstances, both single-phase and two-phase flow may be occurring in the reservoir.
This results when the average reservoir pressure is above the bubblepoint pressure of the reservoir oil while the flowing bottomhole pressure is less than the bubblepoint pressure. The relationship that yields the maximum oil production rate is The flow rate at the bubblepoint pressure, qb, used in Eq. The appropriate J to use in Eqs. If the flowing bottomhole pressure is greater than the bubblepoint pressure, then the well is experiencing single-phase flow conditions and J is determined by The composite IPR is only applicable when the average reservoir pressure is greater than the bubblepoint pressure.
It was based on a series of simulation studies. It yields results similar to two other three-phase flow models   and is easier to implement. The average reservoir pressure for this example is 1, psia. Table 1 Solution To apply the IPR methods, obtain test information, which includes production rates, flowing bottomhole pressures, and an estimate of the average reservoir pressure.
The data obtained at the largest pressure drawdown can be used with Eq. This value is then used to estimate the production rate at other values of flowing bottomhole pressures to develop a complete inflow performance curve.
Table 2 shows the test data prepared for plotting. The data are plotted on a logarithmic graph, which is used to estimate the slope of the best-fit straight line through the data.
The deliverability exponent n is the inverse of the slope. Once n is determined, Eq.
To apply the method of Jones, Blount, and Glaze to this data set, Table 3 was prepared and the data plotted on a coordinate graph as shown in Fig.
The best-fit straight line yielded a slope of 0. The intercept is the laminar flow coefficient and is determined to be 0. These values are used in Eq.