This document provides an overview of reservoir engineering concepts related to analyzing fluid flow in reservoirs, including:
1. It introduces dimensionless variables like dimensionless pressure (pD) that are used to simplify solutions to the diffusivity equation governing fluid flow. pD solutions are presented for both infinite-acting and finite radial reservoirs.
2. Methods for solving the diffusivity equation for compressible (gas) fluids are described, including exact (m(p)-solution) and approximate (pressure-squared, pressure) methods.
3. The dimensionless forms of these solutions - like dimensionless real gas pseudopressure drop (ψD) - are also introduced and their calculation methods explained.
The problem of water and gas coning has plagued the petroleum industry for decades. Water or gas encroachment in oil zone and thus simultaneous production of oil & water or oil & gas is a major technical, environmental and economic problems associated with oil and gas production. This can limit the productive life of the oil and gas wells and can cause severe problems including corrosion of tubulars, fine migration, hydrostatic loading etc. The environmental impact of handling, treating and disposing of the produced water can seriously affect the economics of the production. Commonly, the reservoirs have an aquifer beneath the zone of hydrocarbon. While producing from oil zone, there develops a low pressure zone as a result of which the water zone starts coning upwards and gas zone cones down towards the production perforation in oil zone and thus reducing the oil production. Pressure enhanced capillary transition zone enlargement around the wellbore is responsible for the concurrent production. This also results in the loss of water drive and gas drive to a certain extent.
Numerous technologies have been developed to control unwanted water and gas coning. In order to design an effective strategy to control the coning of oil or gas, it is important to understand the mechanism of coning of oil and gas in reservoirs by developing a model of it. Non-Darcy flow effect (NDFE), vertical permeability, aquifer size, density of well perforation, and flow behind casing increase water coning/inflow to wells in homogeneous gas reservoirs with bottom water are important factors to consider. There are several methods to slow down coning of water and/or gas such as producing at a certain critical rate, polymer injection, Downhole Water Sink (DWS) technology etc.
Shubham Saxena
B.Tech. petroleum Engineering
IIT (ISM) Dhanbad
All hydrocarbon reservoirs are surrounded by water-bearing rocks called aquifers which they effect on reservoir performance. it's a key role for production evaluation and therefore it should be managed.
The problem of water and gas coning has plagued the petroleum industry for decades. Water or gas encroachment in oil zone and thus simultaneous production of oil & water or oil & gas is a major technical, environmental and economic problems associated with oil and gas production. This can limit the productive life of the oil and gas wells and can cause severe problems including corrosion of tubulars, fine migration, hydrostatic loading etc. The environmental impact of handling, treating and disposing of the produced water can seriously affect the economics of the production. Commonly, the reservoirs have an aquifer beneath the zone of hydrocarbon. While producing from oil zone, there develops a low pressure zone as a result of which the water zone starts coning upwards and gas zone cones down towards the production perforation in oil zone and thus reducing the oil production. Pressure enhanced capillary transition zone enlargement around the wellbore is responsible for the concurrent production. This also results in the loss of water drive and gas drive to a certain extent.
Numerous technologies have been developed to control unwanted water and gas coning. In order to design an effective strategy to control the coning of oil or gas, it is important to understand the mechanism of coning of oil and gas in reservoirs by developing a model of it. Non-Darcy flow effect (NDFE), vertical permeability, aquifer size, density of well perforation, and flow behind casing increase water coning/inflow to wells in homogeneous gas reservoirs with bottom water are important factors to consider. There are several methods to slow down coning of water and/or gas such as producing at a certain critical rate, polymer injection, Downhole Water Sink (DWS) technology etc.
Shubham Saxena
B.Tech. petroleum Engineering
IIT (ISM) Dhanbad
All hydrocarbon reservoirs are surrounded by water-bearing rocks called aquifers which they effect on reservoir performance. it's a key role for production evaluation and therefore it should be managed.
calculating reservoir pressure, knowing Depth of gas-oil. oil water interface, GOC AND WOC, numeric method to calculate interface. importance of isobaric maps in estimating reservoir pressure.
Skin factor is a dimensionless parameter that quantifies the formation damage around the wellbore. it also can be negative (which indicates improvement in flow) OR positive (which means formation damage exists). Positive skin can lead to severe well production issues and thus reducing the well revenue
calculating reservoir pressure, knowing Depth of gas-oil. oil water interface, GOC AND WOC, numeric method to calculate interface. importance of isobaric maps in estimating reservoir pressure.
Skin factor is a dimensionless parameter that quantifies the formation damage around the wellbore. it also can be negative (which indicates improvement in flow) OR positive (which means formation damage exists). Positive skin can lead to severe well production issues and thus reducing the well revenue
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Watch this recorded webinar about real-time monitoring of application performance. See how to integrate Apache JMeter, the open-source leader in performance testing, with InfluxDB, the open-source time-series database, and Grafana, the open-source analytics and visualization application.
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Epistemic Interaction - tuning interfaces to provide information for AI supportAlan Dix
Paper presented at SYNERGY workshop at AVI 2024, Genoa, Italy. 3rd June 2024
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2. 1. Multiple-Phase Flow
2. Pressure Disturbance in Reservoirs
3. USS Flow Regime
A. USS: Mathematical Formulation
4. Diffusivity Equation
A. Solution of Diffusivity Equation
a.
Ei- Function Solution
3. 1. Solutions of Diffusivity Equation
A. pD Solution
B. Analytical Solution
2. USS(LT) Regime for Radial flow of SC Fluids:
Finite-Radial Reservoir
3. Relation between pD and Ei
4. USS Regime for Radial Flow of C Fluids
A. (Exact Method)
B. (P2 Approximation Method)
C. (P Approximation Method)
5. PSS regime Flow Constant
4.
5. The Dimensionless Pressure Drop (pD)
Solution
The second form of solution to the diffusivity
equation is called the dimensionless pressure drop.
Well test analysis often makes use of the concept
of the dimensionless variables in solving the
unsteady-state flow equation.
The importance of dimensionless variables is that they
simplify the diffusivity equation and its solution by
combining the reservoir parameters (such as
permeability, porosity, etc.) and thereby reduce the total
number of unknowns.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
5
6. Dimensionless Pressure Drop Solution
Introduction
To introduce the concept of the dimensionless
pressure drop solution, consider for example
Darcy’s equation in a radial form as given previously
by:
Rearrange the above equation to give:
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
6
7. Dimensionless Pressure
It is obvious that the right hand side of the above
equation has no units (i.e., dimensionless) and,
accordingly, the left-hand side must be
dimensionless.
Since the left-hand side is dimensionless, and (pe −
pwf) has the units of psi, it follows that the term
[Qo Bo μo/ (0.00708kh)] has units of pressure.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
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8. pD in Transient Flow Analysis
In transient flow analysis, the dimensionless
pressure pD is always a function of dimensionless
time that is defined by the following expression:
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
8
9. Dimensionless Time
In transient flow analysis, the dimensionless pressure pD is
always a function of dimensionless time that is defined by
the following expression:
The above expression is only one form of the dimensionless
time.
Another definition in common usage is tDA, the
dimensionless time based on total drainage area.
Where A = total drainage area = π re^2, re = drainage radius,
ft, rw = wellbore radius, ft
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
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10. Dimensionless Radial Distances
The dimensionless
pressure pD also varies
with location in the
reservoir as
represented by the
dimensionless radial
distances rD and reD
that are defined by:
Fall 13 H. AlamiNia
Where
pD = dimensionless
pressure drop
reD = dimensionless
external radius
tD = dimensionless time
rD = dimensionless
radius
t = time, hr
p(r, t) = pressure at
radius r and time t
k = permeability, md
μ = viscosity, cp
Reservoir Engineering 1 Course (2nd Ed.)
10
11. Dimensionless Diffusivity Equation
The above dimensionless groups
(i.e., pD, tD, and rD)
can be introduced into the diffusivity equation to
transform the equation into the following
dimensionless form:
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
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12.
13. Analytical Solution Assumptions
Van Everdingen and Hurst (1949) proposed an
analytical solution to the dimensionless diffusivity
equation by assuming:
Perfectly radial reservoir system
The producing well is in the center and producing at a
constant production rate of Q
Uniform pressure pi throughout the reservoir before
production
No flow across the external radius re
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
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14. Van Everdingen and Hurst Solution
Van Everdingen and Hurst presented the solution to
the in a form of infinite series of exponential terms
and Bessel functions.
The authors evaluated this series for several values of
reD over a wide range of values for tD.
Chatas (1953) and Lee (1982) conveniently
tabulated these solutions for the following two
cases:
Infinite-acting reservoir
Finite-radial reservoir
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
14
15. Infinite-Acting Reservoir
When a well is put on production at a constant flow
rate after a shut-in period, the pressure in the
wellbore begins to drop and causes a pressure
disturbance to spread in the reservoir.
The influence of the reservoir boundaries or the shape
of the drainage area does not affect the rate at which
the pressure disturbance spreads in the formation.
That is why the transient state flow is also called
the infinite acting state.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
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16. Parameters Affecting Pwf
during Infinite Acting Period
During the infinite acting period, the declining rate
of wellbore pressure and the manner by which the
pressure disturbance spreads through the reservoir
are determined by reservoir and fluid
characteristics such as:
Porosity, φ
Permeability, k
Total compressibility, ct
Viscosity, μ
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
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17. pD Values for
the Infinite-Acting Reservoir
For an infinite-acting
reservoir, i.e., reD = ∞,
the dimensionless
pressure drop function
pD is strictly a function
of the dimensionless
time tD, or:
Chatas and Lee
tabulated the pD values
for the infinite-acting
reservoir.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
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18. pD Approximation
for the Infinite-Acting Reservoir
The following mathematical expressions can be
used to approximate these tabulated values of pD:
For tD < 0.01:
For tD > 100:
For 0.02 < tD < 1000:
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
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19.
20. Finite-Radial Reservoir
The arrival of the pressure disturbance at the well
drainage boundary marks the end of the transient
flow period and the beginning of the semi
(pseudo)-steady state.
During this flow state, the reservoir boundaries and the
shape of the drainage area influence the wellbore
pressure response as well as the behavior of the
pressure distribution throughout the reservoir.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
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21. Late-Transient State
Intuitively, one should not expect the change from
the transient to the semi-steady state in this
bounded (finite) system to occur instantaneously.
There is a short period of time that separates the
transient state from the semi-steady state that is called
late-transient state.
Due to its complexity and short duration, the late
transient flow is not used in practical well test
analysis.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
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22. pD for a Finite Radial System
For a finite radial system, the pD-function is a
function of both the dimensionless time and radius,
or:
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
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23. pD vs. tD for Finite Radial System
Table presents pD as a
function of tD for 1.5 < reD <
10.
It should be pointed out that
Van Everdingen and Hurst
principally applied the pD
function solution to model the
performance of water influx
into oil reservoirs.
Thus, the authors’ wellbore
radius rw was in this case the
external radius of the
reservoir and the re was
essentially the external
boundary radius of the
aquifer.
Therefore, the range of the
reD values in Table is practical
for this application.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
23
24. pD Calculation
Chatas (1953) proposed the following
mathematical expression for calculating pD:
A special case of above Equation arises when
(reD) ^2>> 1, then:
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
24
25. Using the pD-Function
in Pwf Determination
The computational procedure of using the pD-function
in determining the bottom-hole flowing pressure
changing the transient flow period is summarized in the
following steps:
Step 1. Calculate the dimensionless time tD
Step 2. Calculate the dimensionless radius reD
Step 3. Using the calculated values of tD and reD,
determine the corresponding pressure function pD
from the appropriate table or equation.
Step 4. Solve for the pressure at the desired radius, i.e.,
rw
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
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26.
27. pD-Function vs. Ei-Function Technique
The solution as given by the pD-function technique
is identical to that of the Ei-function approach.
The main difference between the two formulations
is that the pD-function can be used only to calculate
the pressure at radius r when the flow rate Q is
constant and known.
In that case, the pD-function application is essentially restricted
to the wellbore radius because the rate is usually known.
On the other hand, the Ei-function approach can be
used to calculate the pressure at any radius in the
reservoir by using the well flow rate Q.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
27
28. pD Application
In transient flow testing, we normally record the
bottom-hole flowing pressure as a function of time.
Therefore, the dimensionless pressure drop technique
can be used to determine one or more of the reservoir
properties, e.g., k or kh.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
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29. Relation between pD & Ei for Td>100
It should be pointed out that,
for an infinite-acting reservoir with tD > 100,
the pD-function is related to the Ei-function by the following
relation:
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
29
30.
31. Diffusivity Equation
Gas viscosity and density vary significantly with
pressure and
therefore the assumptions of diffusivity equation are not
satisfied for gas systems, i.e., compressible fluids.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
31
32. Diffusivity Equation Calculation:
USS Regime for Radial flow of C Fluids
In order to develop the proper mathematical
function for describing the flow of compressible
fluids in the reservoir:
Combining the above two basic gas equations with
the other equation gives:
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
32
33. Using M (P) for Radial Equation for
Compressible Fluids
Al-Hussainy, Ramey, and Crawford (1966) linearize
the above basic flow equation by introducing the
real gas potential m (p).
Combining above equation with below yields the
radial equation for compressible fluids:
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
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34. Exact Solution of the Equation for
Compressible Fluids
The radial diffusivity equation for compressible
fluids relates the real gas pseudopressure (real gas
potential) to the time t and the radius r.
Al-Hussainy, Ramey, and Crawford (1966) pointed
out that in gas well testing analysis, the constantrate solution has more practical applications than
that provided by the constant pressure solution.
The authors provided the exact solution to the Equation
that is commonly referred to as the m (p)-solution
method.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
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35. Solution Forms of the Equation for
Compressible Fluids
There are also two other solutions that
approximate the exact solution.
In general, there are three forms of the
mathematical solution to the diffusivity equation:
The m (p)-Solution Method (Exact Solution)
The Pressure-Squared Method (p2-Approximation
Method)
The Pressure Method (p-Approximation Method)
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
35
36. The M (P)-Solution Method
(Exact Solution)
Where
Imposing the constant-rate
condition as one of the
boundary conditions
required to solve above
Equation, Al-Hussainy, et al.
(1966) proposed the
following exact solution to
the diffusivity equation:
Fall 13 H. AlamiNia
pwf = bottom-hole flowing
pressure, psi
pe = initial reservoir pressure
Qg = gas flow rate, Mscf/day
t = time, hr
k = permeability, md
T = reservoir temperature
rw = wellbore radius, ft
h = thickness, ft
μi = gas viscosity at the initial
pressure, cp
cti = total compressibility
coefficient at pi, psi−1
φ = porosity
Reservoir Engineering 1 Course (2nd Ed.)
36
37. The M (P)-Solution Method
in Terms of the tD
The m (p)-Solution Equation can be written
equivalently in terms of the dimensionless time tD
as:
The dimensionless time is defined previously as:
The parameter γ is called Euler’s constant and given
by:
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
37
38.
39.
40. Dimensionless
Real Gas Pseudopressure Drop
The solution to the diffusivity equation as given by
(p)-Solution Method expresses the bottom-hole
real gas pseudopressure as a function of the
transient flow time t.
The solution as expressed in terms of m (p) is
recommended mathematical expression for
performing gas-well pressure analysis due to its
applicability in all pressure ranges.
The radial gas diffusivity equation can be expressed
in a dimensionless form in terms of the
dimensionless real gas pseudopressure drop ψD.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
40
41. Solution of Dimensionless Equation
The solution to the dimensionless equation is given
by:
The dimensionless pseudopressure drop ψD can be
determined as a function of tD by using the appropriate
expressions.
When tD > 100, the ψD can be calculated by:
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
41
42. The Pressure-Squared Method
(P2-Approximation Method)
The first approximation to the exact solution is to
remove the pressure- dependent term (μz) outside
the integral that defines m (pwf) and m (pi) to give:
The bars over μ and z represent the values of the
gas viscosity and deviation factor as evaluated at
the average pressure p–. This average pressure is
given by:
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
42
43. Converting M (P)-Solution Method
to P2-Approximation
Combining Equations:
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
43
44. P2-Approximation Assumptions
The Pressure-Squared Method solution forms
indicate that the product (μz) is assumed constant
at the average pressure p–.
This effectively limits the applicability of the p2-method
to reservoir pressures < 2000.
It should be pointed out that when the p2-method is
used to determine pwf it is perhaps sufficient to set μ–
z– = μi z.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
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45.
46. The Pressure Method
(P-Approximation Method)
The second method of approximation to the exact
solution of the radial flow of gases is to treat the
gas as a pseudoliquid.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
46
47. The Pressure Method Equation
Fetkovich (1973)
suggested that at high
pressures (p > 3000),
1/μBg is nearly
constant as shown
schematically in Figure.
Imposing Fetkovich’s
condition gives:
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
47
48. Converting M (P)-Solution Method
to P-Approximation
Combining Equations:
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
48
49. Average Pressure
in P-Approximation Method
It should be noted that the gas properties, i.e., μ,
Bg, and ct, are evaluated at pressure p– as defined
below:
Again, this method is only limited to applications
above 3000 psi.
When solving for pwf, it might be sufficient to evaluate
the gas properties at pi.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
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50.
51. Flash Back: USS
In the unsteady-state flow cases discussed
previously, it was assumed that a well is located in a
very large reservoir and producing at a constant
flow rate.
This rate creates a pressure disturbance in the reservoir
that travels throughout this infinite-size reservoir.
During this transient flow period, reservoir boundaries
have no effect on the pressure behavior of the well.
Obviously, the time period where this assumption can be
imposed is often very short in length.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
51
52. Pseudosteady (Semisteady)-State
Flow Regime
As soon as the pressure disturbance reaches all
drainage boundaries, it ends the transient
(unsteady-state) flow regime.
A different flow regime begins that is called
pseudosteady (semisteady)-state flow.
It is necessary at this point to impose different
boundary conditions on the diffusivity equation and
derive an appropriate solution to this flow regime.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
52
53. Semisteady-State Flow Regime
Figure shows a well in radial
system that is producing at
a constant rate for a long
enough period that
eventually affects the entire
drainage area.
During this semisteadystate flow, the change in
pressure with time
becomes the same
throughout the drainage
area.
Section B shows that the
pressure distributions
become paralleled at
successive time periods.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
53
54. PSS Constant
The important PSS condition can be expressed as:
The constant referred to in the above equation can
be obtained from a simple material balance using
the definition of the compressibility, thus:
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
54
55. Pressure Decline Rate
Expressing the pressure decline rate dp/dt in the
above relation in psi/hr gives:
Where q = flow rate, bbl/day
Qo = flow rate, STB/day
dp/dt = pressure decline rate, psi/hr
V = pore volume, bbl
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
55
56. Pressure Decline Rate
for Radial Drainage System
For a radial drainage system, the pore volume is
given by:
Where A = drainage area, ft2
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
56
57. Characteristics of
the Pressure Behavior during PSS
Examination reveals the following important
characteristics of the behavior of the pressure
decline rate dp/dt during the semisteady-state flow:
The reservoir pressure declines at a higher rate with an
increase in the fluids production rate
The reservoir pressure declines at a slower rate for
reservoirs with higher total compressibility coefficients
The reservoir pressure declines at a lower rate for
reservoirs with larger pore volumes
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
57
58. Semisteady-State Condition
Matthews, Brons, and Hazebroek (1954) pointed
out that once the reservoir is producing under the
semisteady-state condition,
Each well will drain from within its own no-flow
boundary independently of the other wells.
For this condition to prevail:
The pressure decline rate dp/dt must be approximately
constant throughout the entire reservoir,
Otherwise, flow would occur across the boundaries
causing a readjustment in their positions.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
58
59. 1. Ahmed, T. (2010). Reservoir engineering
handbook (Gulf Professional Publishing).
Chapter 6
60. 1. PSS Regime
A.
B.
C.
D.
Average Reservoir Pressure
PSS regime for Radial Flow of SC Fluids
Effect of Well Location within the Drainage Area
PSS Regime for Radial Flow of C Fluids
2. Skin Concept
3. Using S for Radial Flow in Flow Equations
4. Turbulent Flow