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Reservoir Engineering 1 Course ( 1 st Ed.)

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1. PSSA. Average Reservoir Pressure

B. PSS regime for Radial Flow of SC Fluids

C. Effect of Well Location within the Drainage Area

D. PSS Regime for Radial Flow of C Fluids

2. Skin Concept

3. Using S for Radial Flow in Flow Equations

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1. Turbulent Flow

2. SuperpositionA. Multiple Well

B. Multi Rate

C. Reservoir Boundary

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Turbulent Vs. Laminar Flow

All of the mathematical formulations presented so far are based on the assumption that laminar flow conditions are observed during flow.

During radial flow, the flow velocity increases as the wellbore is approached. This increase in the velocity might cause the

development of a turbulent flow around the wellbore.

2013 H. AlamiNia Reservoir Engineering 1 Course: Turbulent Flow and Superposition 5

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Turbulent (Non-Darcy) Flow

If turbulent flow does exist, it is most likely to occur with gases and causes an additional pressure drop similar to that caused by the skin effect.

The term non-Darcy flow has been adopted by the industry to describe the additional pressure drop due to the turbulent (non-Darcy) flow.

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Turbulent Flow Factor

Referring to the additional real gas pseudopressure drop due to non- Darcy flow as Δψ non-Darcy, the total (actual) drop is given by:

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Non-Darcy Flow Coefficient

Wattenburger and Ramey (1968) proposed the following expression for calculating (Δψ) non-Darcy:

Where:Qg = gas flow rate, Mscf/dayμgw = gas viscosity as evaluated at pwf, cpγg = gas specific gravityh = thickness, ftF = non-Darcy flow coefficient, psi2/cp/ (Mscf/day) 2β = turbulence parameter

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Turbulence Parameter

Jones (1987) proposed a mathematical expression for estimating the turbulence parameter β as:

Where:k = permeability, md

φ = porosity, fraction

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USS Regime in Radial flow for C Fluids (Turbulent Flow)The gas flow equation for an unsteady-state flow

can be modified to include the additional drop in the real gas potential as:

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Inertial or Turbulent Flow Factor

The term DQg is interpreted as the rate dependent skin factor. The coefficient D is called the inertial or turbulent flow

factor and given by:

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Apparent (Total) Skin Factor

The true skin factor s, which reflects the formation damage or stimulation, is usually combined with the non-Darcy rate dependent skin and labeled as the apparent or total skin factor:

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USS Regime in Radial flow for C Fluids (Turbulent Flow) (Cont.)

Where:Qg = gas flow rate, Mscf/dayt = time, hrk = permeability, mdμi = gas viscosity as evaluated at pi, cp

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PSS Regime in Radial flow for C Fluids (Turbulent Flow)

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SS Regime in Radial Flow for C Fluids (Turbulent Flow)

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Flash Back: Solutions to the Radial Diffusivity EquationThe solutions to the radial diffusivity equation

appear to be applicable only for describing the pressure distribution in an infinite reservoir that was caused by a constant production from a single well.

Since real reservoir systems usually have several wells that are operating at varying rates, a more generalized approach is needed to study the fluid flow behavior during the unsteady state flow period.

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Superposition Theorem

The principle of superposition is a powerful concept that can be applied to remove the restrictions that have been imposed on various forms of solution to the transient flow equation.

Mathematically the superposition theorem states that any sum of individual solutions to the diffusivity equation is also a solution to that equation.

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Superposition Concept Applications

Superposition concept can be applied to account for the following effects on the transient flow solution:Effects of multiple wells

Effects of rate change

Effects of the boundary

Effects of pressure change

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Effects of Multiple Wells

Frequently, it is desired to account for the effects of more than one well on the pressure at some point in the reservoir.

The superposition concept states that the total pressure drop at any point in the reservoir is the sum of the pressure changes at that point caused by flow in each of the wells in the reservoir. In other words, we simply superimpose one effect upon

the other.

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Appling Superposition: Effects of Multiple WellsFigure shows three

wells that are producing at different flow rates from an infinite acting reservoir, i.e., unsteady-state flow reservoir. The principle of superposition shows that the total pressure drop observed at any well, e.g., Well 1, is:

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Appling Superposition: Effects of Multiple Wells (Cont.) The pressure drop at Well 1 due to

its own production is given by the log-approximation to the Ei-function solution presented by: (Qo1=oil flow rate from well 1)

The pressure drop at Well 1 due to production at Wells 2 and 3 must be written in terms of the Ei-function solution. The log-approximation cannot be used because we are calculating the pressure at a large distance r from the well, i.e., the argument x > 0.01, or:

It should also be noted that if the point of interest is an operating well, the skin factor s must be included for that well only.

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Effects of Rate Change

All of the mathematical expressions presented previously require that the wells produce at a constant rate during the transient flow periods.

Practically all wells produce at varying rates and, therefore, it is important that we be able to predict the pressure behavior when the rate changes.

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Superposition: Effects of Rate Change

For predicting the pressure behavior when the rate changes, the concept of superposition states:“Every flow rate change in a well will result in a pressure

response which is independent of the pressure responses caused by other previous rate changes.”

Accordingly, the total pressure drop that has occurred at any time is the summation of pressure changes caused separately by each net flow rate change.

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Production and Pressure History of a Multi-Rate WellConsider the

case of a shut-in well, i.e., Q = 0, that was then allowed to produce at a series of constant rates for the different time periods shown in Figure.

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Pressure Drop of Multi-Rate Well

To calculate the total pressure drop at the sand face at time t4, the composite solution is obtained by adding the individual constant-rate solutions at the specified rate-time sequence, or:

The above expression indicates that there are four contributions to the total pressure drop resulting from the four individual flow rates.

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Pressure Drop of Multi-Rate Well: 1st ContributionThe first contribution results from increasing the rate

from 0 to Q1 and is in effect over the entire time period t4, thus:

It is essential to notice the change in the rate, i.e., (new rate − old rate), that is used in the above equation. It is the change in the rate that causes the pressure

disturbance.

Further, it should be noted that the “time” in the equation represents the total elapsed time since the change in the rate has been in effect.

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Pressure Drop of Multi-Rate Well: Other ContributionsSecond contribution results from decreasing the

rate from Q1 to Q2 at t1, thus:

Note, however, the above approach is valid only if the well is flowing under the unsteady-state flow condition for the total time elapsed since the well began to flow at its initial rate.

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Effects of the Boundary

The superposition theorem can also be extended to predict the pressure of a well in a bounded reservoir. Figure, which

shows a well that is located at distance r from the non-flow boundary, e.g., sealing fault.

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Method of Images in Solving Boundary ProblemsThe no-flow boundary can be represented by the

following pressure gradient expression:

Mathematically, the above boundary condition can be met by placing an image well, identical to that of the actual well, on the other side of the fault at exactly distance r.

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Method of Images

Consequently, the effect of the boundary on the pressure behavior of a well would be the same as the effect from an image well located a distance 2r from the actual well.

In accounting for the boundary effects, the superposition method is frequently called the method of images.

Thus, for a well that is located at distance r from the non-flow boundary, the problem reduces to one of determining the effect of the image well on the actual well.

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Method of Images (Cont.)

The total pressure drop at the actual well will be the pressure drop due to its own production plus the additional pressure drop caused by an identical well at a distance of 2r, or:

Notice that this equation assumes the reservoir is infinite except for the indicated boundary.

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Extension of the Image Wells Concept

The effect of boundaries is always to cause greater pressure drop than those calculated for infinite reservoirs.

The concept of image wells can be extended to generate the pressure behavior of a well located within a variety of boundary configurations.

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Effects of Pressure Change

Superposition is also used in applying the constant-pressure case.

Pressure changes are accounted for in this solution in much the same way that rate changes are accounted for in the constant rate case.

The superposition method to account for the pressure-change effect is used in the Water Influx.

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Transient Well Testing

Detailed reservoir information is essential to the petroleum engineer in order to analyze the current behavior and future performance of the reservoir.

Pressure transient testing is designed to provide the engineer with a quantitative analysis of the reservoir properties. A transient test is essentially conducted by creating a

pressure disturbance in the reservoir and recording the pressure response at the wellbore, i.e., bottom-hole flowing pressure pwf, as a function of time.

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Pressure Transient Tests

The pressure transient tests most commonly used in the petroleum industry include:Pressure drawdown

Pressure buildup

Multirate

Interference

Pulse

Drill stem

Fall off

Injectivity

Step rate

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Information Available From a Well Test

It has long been recognized that the pressure behavior of a reservoir following a rate change directly reflects the geometry and flow properties of the reservoir.

Information available from a well test includes:Effective permeabilityFormation damage or stimulationFlow barriers and fluid contactsVolumetric average reservoir pressureDrainage pore volumeDetection, length, capacity of fracturesCommunication between wells

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1. Ahmed, T. (2006). Reservoir engineering handbook (Gulf Professional Publishing). Ch6

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