Drill stem test (DST) is one of the most famous on-site well testing that is used to unveil critical reservoir and fluid properties such as reservoir pressure, average permeability, skin factor and well potential productivity index. It is relatively cheap on-site test that is done prior to well completion. Upon the DST results, usually, the decision of the well completion is taken.
Drill stem test (DST) is one of the most famous on-site well testing that is used to unveil critical reservoir and fluid properties such as reservoir pressure, average permeability, skin factor and well potential productivity index. It is relatively cheap on-site test that is done prior to well completion. Upon the DST results, usually, the decision of the well completion is taken.
Эффективный мониторинг работы нагнетательных скважин при заводненииMikhail Tuzovskiy
Оптимизация системы поддержания пластового давления (ППД) на Самотлорском месторождении является одной из приоритетных задач компании ТНК-ВР. Для эффективной работы всей системы ППД в целом необходимо иметь инструменты для контроля над работой каждой нагнетательной скважины в частности. Недооценка необходимости такого контроля может привести к падению пластового давления, преждевременным прорывам воды, потери закачиваемой жидкости из-за неконтролируемого образования трещин и, как следствие, снижению коэффициента вытеснения и снижению КИНа.
В данной статье предлагается системный подход для эффективного мониторинга работы нагнетательных скважин, разработанный для пласта АВ1(1-2) («Рябчик») Самотлорского месторождения, который, в конечном итоге, позволяет определять оптимальные приемистость и давления закачки при заводнении.
21 Rock Fluid Interactions Capillary Rise, Capillary Pressure, J.docxeugeniadean34240
21 Rock Fluid Interactions Capillary Rise, Capillary Pressure, J Functions.pdf
107
Petr 3520: Rock-Fluid Interactions (such as capillary rise, capillary pressure…) Class 21
So far in this class we have studied rock properties (, k, cf, etc.) and fluid properties. But reservoir
engineers must also understand immiscible fluid-fluid interactions and rock-fluid interactions.
In petroleum reservoirs we have:
1. Microscopic-sized pores + two or more (immiscible) fluids (oil-water, gas-water, or oil-gas-
water) which typically do not mix (they are immiscible, not miscible). The rocks are water-wet or oil-wet
(which means that the rock is preferentially wetted by water or oil).
Because the pores are so small, the surface area (fluid-rock contact, and fluid-fluid contact (for example,
oil to water)) to volume (of fluid and/or rock) is very high, thus surface forces become significant.
Example Calculation: 1 ft
3
cube of rock, assume to be bundle of 1 mm dia tubes each 1 ft = 304.8 mm
long. There are 300
2
= 90,000 tubes in this cube. Surface area in mm
2
, convert to ft
2
: A = 1000 ft
2
.
2. What are surface forces? Surface forces exist at (immiscible) liquid-liquid and liquid-solid interfaces.
Surface forces arise due to relative Adhesion vs. Cohesion.
Cohesion (“stick or stay together”) is a property of a fluid whose molecules have high intermolecular
attraction. The fluid’s molecules would rather stick to themselves rather than another fluid or nearby
surface.
Adhesion is the degree to which a fluid will “stick” to a nearby solid surface.
3. Wetting, Contact Angle: These are the result of the relative cohesion vs. adhesion of two fluids and a
solid surface.
Fluid “wets” a surface: Adhesion > Cohesion. The fluid’s molecules preferentially attracted to
surface.
Fluid does not “wet” the surface: Cohesion > Adhesion. The fluid’s molecules preferentially
attracted to fluid.
Contact Angle: Angle formed between a fluid drop and a solid surface, measured through the fluid.
4. Examples of wettability, contact angle (): A fluid’s interaction with a solid surface:
Rain-X on automobile windshields
Gore Tex fabric
Non-stick fry pans
5. Examples of a fluid’s cohesion vs. adhesion (relative affinity of a fluid’s molecules to itself or to a solid
surface)
Round drops on plant leaves, on non-stick frying pans (for a fluid to form drops like this, the
fluid’s molecules would rather cohere with other fluid molecules than adhere to a solid surface)
6. Surface tension (): Between a fluid’s surface and air. Units: [work/area] = [dyne-cm/cm
2
] A fluid
wants to minimize its free surface. It takes work or energy to create additional surface area.
Free fluids form drops (minimum surface area)
Round drops on plants (cohesion
Water bugs
Coin or paper clip float on water
108
7. Interfacial tension (): Between two fluids, e.g. .
Manipulation of Water Hammer Problem by Modification of NRV ValveIDES Editor
Water hammer in piping systems produces large
dynamic forces which can damage the pipes and supports.
Therefore it is important to minimize the water hammer
effects on the piping system. In this work, a new method for
the reduction of water hammer by active measures is
described- that means the reduction of water hammer by
influencing the fluid dynamic conditions of the system. We
are concerned with the effects of the rapid valve closures in
pipes connected to wave reflection points. The energy is of
two kind’s Kinetic energy and Elastic energy. Both forms are
converted into pressure energy and the rapidity of the
conversion is of the utmost importance in terms of ensuring
damage that may result. Such energy dissipation in a
controlled non damaging way is discussed in this paper. The
latest outcomes of the research in this area are also discussed
with their failures in the implementation of these concepts in
industries, and the feasibility of our new method
Transcript: Selling digital books in 2024: Insights from industry leaders - T...BookNet Canada
The publishing industry has been selling digital audiobooks and ebooks for over a decade and has found its groove. What’s changed? What has stayed the same? Where do we go from here? Join a group of leading sales peers from across the industry for a conversation about the lessons learned since the popularization of digital books, best practices, digital book supply chain management, and more.
Link to video recording: https://bnctechforum.ca/sessions/selling-digital-books-in-2024-insights-from-industry-leaders/
Presented by BookNet Canada on May 28, 2024, with support from the Department of Canadian Heritage.
Smart TV Buyer Insights Survey 2024 by 91mobiles.pdf91mobiles
91mobiles recently conducted a Smart TV Buyer Insights Survey in which we asked over 3,000 respondents about the TV they own, aspects they look at on a new TV, and their TV buying preferences.
Essentials of Automations: Optimizing FME Workflows with ParametersSafe Software
Are you looking to streamline your workflows and boost your projects’ efficiency? Do you find yourself searching for ways to add flexibility and control over your FME workflows? If so, you’re in the right place.
Join us for an insightful dive into the world of FME parameters, a critical element in optimizing workflow efficiency. This webinar marks the beginning of our three-part “Essentials of Automation” series. This first webinar is designed to equip you with the knowledge and skills to utilize parameters effectively: enhancing the flexibility, maintainability, and user control of your FME projects.
Here’s what you’ll gain:
- Essentials of FME Parameters: Understand the pivotal role of parameters, including Reader/Writer, Transformer, User, and FME Flow categories. Discover how they are the key to unlocking automation and optimization within your workflows.
- Practical Applications in FME Form: Delve into key user parameter types including choice, connections, and file URLs. Allow users to control how a workflow runs, making your workflows more reusable. Learn to import values and deliver the best user experience for your workflows while enhancing accuracy.
- Optimization Strategies in FME Flow: Explore the creation and strategic deployment of parameters in FME Flow, including the use of deployment and geometry parameters, to maximize workflow efficiency.
- Pro Tips for Success: Gain insights on parameterizing connections and leveraging new features like Conditional Visibility for clarity and simplicity.
We’ll wrap up with a glimpse into future webinars, followed by a Q&A session to address your specific questions surrounding this topic.
Don’t miss this opportunity to elevate your FME expertise and drive your projects to new heights of efficiency.
GDG Cloud Southlake #33: Boule & Rebala: Effective AppSec in SDLC using Deplo...James Anderson
Effective Application Security in Software Delivery lifecycle using Deployment Firewall and DBOM
The modern software delivery process (or the CI/CD process) includes many tools, distributed teams, open-source code, and cloud platforms. Constant focus on speed to release software to market, along with the traditional slow and manual security checks has caused gaps in continuous security as an important piece in the software supply chain. Today organizations feel more susceptible to external and internal cyber threats due to the vast attack surface in their applications supply chain and the lack of end-to-end governance and risk management.
The software team must secure its software delivery process to avoid vulnerability and security breaches. This needs to be achieved with existing tool chains and without extensive rework of the delivery processes. This talk will present strategies and techniques for providing visibility into the true risk of the existing vulnerabilities, preventing the introduction of security issues in the software, resolving vulnerabilities in production environments quickly, and capturing the deployment bill of materials (DBOM).
Speakers:
Bob Boule
Robert Boule is a technology enthusiast with PASSION for technology and making things work along with a knack for helping others understand how things work. He comes with around 20 years of solution engineering experience in application security, software continuous delivery, and SaaS platforms. He is known for his dynamic presentations in CI/CD and application security integrated in software delivery lifecycle.
Gopinath Rebala
Gopinath Rebala is the CTO of OpsMx, where he has overall responsibility for the machine learning and data processing architectures for Secure Software Delivery. Gopi also has a strong connection with our customers, leading design and architecture for strategic implementations. Gopi is a frequent speaker and well-known leader in continuous delivery and integrating security into software delivery.
Elevating Tactical DDD Patterns Through Object CalisthenicsDorra BARTAGUIZ
After immersing yourself in the blue book and its red counterpart, attending DDD-focused conferences, and applying tactical patterns, you're left with a crucial question: How do I ensure my design is effective? Tactical patterns within Domain-Driven Design (DDD) serve as guiding principles for creating clear and manageable domain models. However, achieving success with these patterns requires additional guidance. Interestingly, we've observed that a set of constraints initially designed for training purposes remarkably aligns with effective pattern implementation, offering a more ‘mechanical’ approach. Let's explore together how Object Calisthenics can elevate the design of your tactical DDD patterns, offering concrete help for those venturing into DDD for the first time!
Accelerate your Kubernetes clusters with Varnish CachingThijs Feryn
A presentation about the usage and availability of Varnish on Kubernetes. This talk explores the capabilities of Varnish caching and shows how to use the Varnish Helm chart to deploy it to Kubernetes.
This presentation was delivered at K8SUG Singapore. See https://feryn.eu/presentations/accelerate-your-kubernetes-clusters-with-varnish-caching-k8sug-singapore-28-2024 for more details.
Generative AI Deep Dive: Advancing from Proof of Concept to ProductionAggregage
Join Maher Hanafi, VP of Engineering at Betterworks, in this new session where he'll share a practical framework to transform Gen AI prototypes into impactful products! He'll delve into the complexities of data collection and management, model selection and optimization, and ensuring security, scalability, and responsible use.
A tale of scale & speed: How the US Navy is enabling software delivery from l...sonjaschweigert1
Rapid and secure feature delivery is a goal across every application team and every branch of the DoD. The Navy’s DevSecOps platform, Party Barge, has achieved:
- Reduction in onboarding time from 5 weeks to 1 day
- Improved developer experience and productivity through actionable findings and reduction of false positives
- Maintenance of superior security standards and inherent policy enforcement with Authorization to Operate (ATO)
Development teams can ship efficiently and ensure applications are cyber ready for Navy Authorizing Officials (AOs). In this webinar, Sigma Defense and Anchore will give attendees a look behind the scenes and demo secure pipeline automation and security artifacts that speed up application ATO and time to production.
We will cover:
- How to remove silos in DevSecOps
- How to build efficient development pipeline roles and component templates
- How to deliver security artifacts that matter for ATO’s (SBOMs, vulnerability reports, and policy evidence)
- How to streamline operations with automated policy checks on container images
Observability Concepts EVERY Developer Should Know -- DeveloperWeek Europe.pdfPaige Cruz
Monitoring and observability aren’t traditionally found in software curriculums and many of us cobble this knowledge together from whatever vendor or ecosystem we were first introduced to and whatever is a part of your current company’s observability stack.
While the dev and ops silo continues to crumble….many organizations still relegate monitoring & observability as the purview of ops, infra and SRE teams. This is a mistake - achieving a highly observable system requires collaboration up and down the stack.
I, a former op, would like to extend an invitation to all application developers to join the observability party will share these foundational concepts to build on:
Encryption in Microsoft 365 - ExpertsLive Netherlands 2024Albert Hoitingh
In this session I delve into the encryption technology used in Microsoft 365 and Microsoft Purview. Including the concepts of Customer Key and Double Key Encryption.
Dev Dives: Train smarter, not harder – active learning and UiPath LLMs for do...UiPathCommunity
💥 Speed, accuracy, and scaling – discover the superpowers of GenAI in action with UiPath Document Understanding and Communications Mining™:
See how to accelerate model training and optimize model performance with active learning
Learn about the latest enhancements to out-of-the-box document processing – with little to no training required
Get an exclusive demo of the new family of UiPath LLMs – GenAI models specialized for processing different types of documents and messages
This is a hands-on session specifically designed for automation developers and AI enthusiasts seeking to enhance their knowledge in leveraging the latest intelligent document processing capabilities offered by UiPath.
Speakers:
👨🏫 Andras Palfi, Senior Product Manager, UiPath
👩🏫 Lenka Dulovicova, Product Program Manager, UiPath
DevOps and Testing slides at DASA ConnectKari Kakkonen
My and Rik Marselis slides at 30.5.2024 DASA Connect conference. We discuss about what is testing, then what is agile testing and finally what is Testing in DevOps. Finally we had lovely workshop with the participants trying to find out different ways to think about quality and testing in different parts of the DevOps infinity loop.
2. 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
3. 1. Superposition
A. Multiple Well
B. Multi Rate
C. Reservoir Boundary
2. Productivity Index (PI)
3. Inflow Performance Relationship (IPR)
4.
5. Flash Back: Solutions
to the Radial Diffusivity Equation
The 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.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
5
6. 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.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
6
7. 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
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
7
8. 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.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
8
9. Appling Superposition:
Effects of Multiple Wells
Figure 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:
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
9
10. 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:
Fall 13 H. AlamiNia
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.
Reservoir Engineering 1 Course (2nd Ed.)
10
11.
12. 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.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
12
13. 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.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
13
14. Production and
Pressure History of a Multi-Rate Well
Consider the
case of a shutin 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.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
14
15. 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.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
15
16. Pressure Drop of Multi-Rate Well:
1st Contribution
The 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.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
16
17. Pressure Drop of Multi-Rate Well:
Other Contributions
Second 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.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
17
18.
19. 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 nonflow boundary,
e.g., sealing
fault.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
19
20. Method of Images
in Solving Boundary Problems
The 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.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
20
21. 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.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
21
22. 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.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
22
23. 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.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
23
24. Effects of Pressure Change
Superposition is also used in applying the constantpressure 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.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
24
25. 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.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
25
26. 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
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
26
27. 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 permeability
Formation damage or stimulation
Flow barriers and fluid contacts
Volumetric average reservoir pressure
Drainage pore volume
Detection, length, capacity of fractures
Communication between wells
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
27
28.
29.
30. Well Performance
These lectures presents the practical reservoir
engineering equations that are designed to predict
the performance of vertical and horizontal wells.
Also describe some of the factors that are governing the
flow of fluids from the formation to the wellbore and
how these factors may affect the production
performance of the well.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
30
31. Production Performance Analysis
The analysis of the production performance is
essentially based on the following fluid and well
characteristics:
Fluid PVT properties
Relative permeability data
Inflow-performance-relationship (IPR)
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
31
32. Productivity Index
A commonly used measure
of the ability of the well to
produce is the Productivity
Index.
Defined by the symbol J,
the productivity index is the
ratio of the total liquid flow
rate to the pressure
drawdown.
For a water-free oil
production, the
productivity index is given
by:
Fall 13 H. AlamiNia
Where
Qo = oil flow rate,
STB/day
J = productivity index,
STB/day/psi
p–r = volumetric
average drainage area
pressure (static
pressure)
pwf = bottom-hole
flowing pressure
Δp = drawdown, psi
Reservoir Engineering 1 Course (2nd Ed.)
32
33. Productivity Index Measurement
The productivity index is generally measured during
a production test on the well.
The well is shut-in until the static reservoir pressure is
reached.
The well is then allowed to produce at a constant flow rate of Q
and a stabilized bottom-hole flow pressure of pwf.
Since a stabilized pressure at surface does not necessarily
indicate a stabilized pwf, the bottom-hole flowing pressure
should be recorded continuously from the time the well is to
flow.
The productivity index is then calculated from:
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
33
34. Productivity Index Conditions
It is important to note that the productivity index is
a valid measure of the well productivity potential
only if the well is flowing at pseudosteady-state
conditions.
Therefore, in order to accurately measure the
productivity index of a well, it is essential that the well is
allowed to flow at a constant flow rate for a sufficient
amount of time to reach the pseudosteady-state.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
34
35. Productivity Index during Flow
Regimes
The figure
indicates that
during the
transient flow
period,
the calculated
values of the
productivity
index will vary
depending
upon the time
at which the
measurement
s of pwf are
made.
Productivity index during flow regimes
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
35
36. Productivity Index Calculation
The productivity index can be numerically
calculated by recognizing that J must be defined in
terms of semisteady-state flow conditions.
Recalling below Equation:
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
36
37. Application of Productivity Index
Since most of the well life is spent in a flow regime
that is approximating the pseudosteady-state, the
productivity index is a valuable methodology for
predicting the future performance of wells.
Further, by monitoring the productivity index during the
life of a well, it is possible to determine if the well has
become damaged due to completion, workover,
production, injection operations, or mechanical
problems.
If a measured J has an unexpected decline, one of the indicated
problems should be investigated.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
37
38. Specific Productivity Index
A comparison of productivity indices of different
wells in the same reservoir should also indicate
some of the wells might have experienced unusual
difficulties or damage during completion.
Since the productivity indices may vary from well to well
because of the variation in thickness of the reservoir, it is
helpful to normalize the indices by dividing each by the
thickness of the well.
This is defined as the specific productivity index Js, or:
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
38
39.
40. Qo vs. Δp Relationship
Assuming that the well’s
productivity index is
constant:
Where
Δp = drawdown, psi
J = productivity index
The Equation indicates
that the relationship
between Qo and Δp is a
straight line passing
through the origin with a
slope of J as shown in
Figure.
Qo vs. Δp relationship
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
40
41. Inflow Performance Relationship
Alternatively, productivity
Index Equation can be written
as:
The above expression shows
that the plot pwf against Qo is
a straight line with a slope of
(−1/J) as shown schematically
in Figure.
This graphical representation
of the relationship that exists
between the oil flow rate and
bottom-hole flowing pressure
is called the inflow
performance relationship and
referred to as IPR.
Qo STB/day
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
41
42. Features of the Straight-Line IPR
Several important features of the straight-line IPR
can be seen in Figure:
When pwf equals average reservoir pressure, the flow
rate is zero due to the absence of any pressure
drawdown.
Maximum rate of flow occurs when pwf is zero. This
maximum rate is called absolute open flow and referred
to as AOF.
The slope of the straight line equals the reciprocal of the
productivity index.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
42
43. Absolute Open Flow
Although in practice AOF may not be a condition at
which the well can produce,
It is a useful definition that has widespread applications
in the petroleum industry
(e.g., comparing flow potential of different wells in the field).
The AOF is then calculated by:
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
43
44. IPR For Below Pb
(Qo=JΔP) suggests that the
inflow into a well is directly
proportional to the
pressure drawdown and
the constant of
proportionality is the
productivity index.
Muskat and Evinger (1942)
and Vogel (1968) observed
that when the pressure
drops below the bubblepoint pressure, the IPR
deviates from that of the
simple straight-line
relationship as shown in
Figure.
IPR below pb
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
44
45. Pressure Dependent Variables
Affecting PI
Recalling following
Equation:
Treating the term
between the two
brackets as a constant c,
the above equation can
be written in the
following form:
Fall 13 H. AlamiNia
Above equation reveals
that the variables
affecting the
productivity index are
essentially those that
are pressure
dependent, i.e.:
Oil viscosity μo
Oil formation volume
factor Bo
Relative permeability to
oil kro
Reservoir Engineering 1 Course (2nd Ed.)
45
46. Schematically Illustration of the
Variables as a Function of P
Effect of pressure on Bo, μo, and kro
Fall 13 H. AlamiNia
kro/μoBo as a function of pressure
Reservoir Engineering 1 Course (2nd Ed.)
46
47. Behavior of Pressure Dependent
Variables
Above the bubble-point pressure pb
The relative oil permeability kro equals unity (kro = 1)
and the term (kro/μoBo) is almost constant.
As the pressure declines below pb:
The gas is released from solution, which can cause a
large decrease in both kro and (kro/μoBo).
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
47
48. Effect of Reservoir Pressure on IPR
Figure shows
qualitatively
the effect of
reservoir
depletion on
the IPR.
Effect of reservoir pressure on IPR
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
48
49. Empirical Methods
to Predict NL Behavior of IPR
Several empirical methods are designed to predict
the non-linearity behavior of the IPR for solution
gas drive reservoirs.
Most of these methods require at least one stabilized
flow test in which Qo and pwf are measured.
All the methods include the following two computational
steps:
Using the stabilized flow test data, construct the IPR curve at
the current average reservoir pressure p–r.
Predict future inflow performance relationships as to the
function of average reservoir pressures.
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
49
50. Empirical Methods to Generate IPR
The following empirical methods that are designed
to generate the current and future inflow
performance relationships:
Vogel’s Method
Wiggins’ Method
Standing’s Method
Fetkovich’s Method
The Klins-Clark Method
Fall 13 H. AlamiNia
Reservoir Engineering 1 Course (2nd Ed.)
50
51. 1. Ahmed, T. (2010). Reservoir engineering
handbook (Gulf Professional Publishing).
Chapter 6 and 7
52. 1. Generating IPR for Oil Wells
A. Vogel’s Method
B. Vogel’s Method (Undersaturated Reservoirs)
a.
Future IPR Approximation
C. Wiggins’ Method
D. Standing’s Method
E. Fetkovich’s Method