This document discusses concepts in applied reservoir engineering. It defines key reservoir terms like reservoir rock, cap rock, and reservoir fluids. It also covers rock and fluid properties important for reservoir characterization like porosity, permeability, and PVT properties. Methods for calculating original hydrocarbon in place are presented, including volumetric and material balance approaches. Determining reservoir drive mechanisms and predicting future performance through primary and secondary recovery methods are also summarized.
prediction of original oil in place using material balance simulation. It's also useful for future reservoir performance and predict ultimate hydrocarbon recovery under various types of primary driving mechanisms.
prediction of original oil in place using material balance simulation. It's also useful for future reservoir performance and predict ultimate hydrocarbon recovery under various types of primary driving mechanisms.
Reservoir engineers cannot capture full value from waterflood projects on their own. Cross-functional participation from earth sciences, production, drilling, completions, and facility engineering, and operational groups is required to get full value from waterfloods. Waterflood design and operational case histories of cross-functional collaboration are provided that have improved life cycle costs and increased recovery for onshore and offshore waterfloods. The role that water quality, surveillance, reservoir processing rates, and layered reservoir management has on waterflood oil recovery and life cycle costs will be clarified. Techniques to get better performance out of your waterflood will be shared.
Reservoir engineering is the field to evaluate field performance by performing reservoir modeling studies and explore opportunities to maximize the value of both exploration and production properties to enhance hydrocarbon production.
This lecture reviews hydraulic fracturing and alternative fracturing technologies, by searching the open literature, patent databases and commercial websites.
For each identified technique, an overview is given.
The technique is then briefly explained, and its rationale (reasons for use) is identified. Potential advantages and disadvantages are identified, and some considerations on costs are given.
Finally, the status of the technique (for instance, commercially applied, being developed, concept, etc.) is given for its application to shale gas production.
Why Unconventional Gas Reservoirs need to be Hydraulically Fractured; The importance of complex hydraulic fracture geometry; The Hydraulic Fracturing Process described; Fracturing Materials; What Can We Control During a Fracture Treatment?; Why cause and effect with respect to production are not always obvious; Key Considerations for Hydraulic Fracturing of Gas Shales; Why We Fracture Shale Gas Wells…!; The Hydraulic Fracturing Processes; Functions of the Fracturing Fluid; Fracturing Challenges in Unconventional Gas Reservoirs; Post Fracture Treatment Monitoring Methods; Fracture Treatment Validation Via Microseismic Monitoring
Overview of Reservoir Simulation by Prem Dayal Saini
Reservoir simulation is the study of how fluids flow in a hydrocarbon reservoir when put under production conditions. The purpose is usually to predict the behavior of a reservoir to different production scenarios, or to increase the understanding of its geological properties by comparing known behavior to a simulation using different geological representations.
Production decline analysis is a traditional means of identifying well production problems and predicting well performance and life based on real production data. It uses empirical decline models that have little fundamental justifications. These models include
•
Exponential decline (constant fractional decline)
•
Harmonic decline, and
•
Hyperbolic decline.
Reservoir engineers cannot capture full value from waterflood projects on their own. Cross-functional participation from earth sciences, production, drilling, completions, and facility engineering, and operational groups is required to get full value from waterfloods. Waterflood design and operational case histories of cross-functional collaboration are provided that have improved life cycle costs and increased recovery for onshore and offshore waterfloods. The role that water quality, surveillance, reservoir processing rates, and layered reservoir management has on waterflood oil recovery and life cycle costs will be clarified. Techniques to get better performance out of your waterflood will be shared.
Reservoir engineering is the field to evaluate field performance by performing reservoir modeling studies and explore opportunities to maximize the value of both exploration and production properties to enhance hydrocarbon production.
This lecture reviews hydraulic fracturing and alternative fracturing technologies, by searching the open literature, patent databases and commercial websites.
For each identified technique, an overview is given.
The technique is then briefly explained, and its rationale (reasons for use) is identified. Potential advantages and disadvantages are identified, and some considerations on costs are given.
Finally, the status of the technique (for instance, commercially applied, being developed, concept, etc.) is given for its application to shale gas production.
Why Unconventional Gas Reservoirs need to be Hydraulically Fractured; The importance of complex hydraulic fracture geometry; The Hydraulic Fracturing Process described; Fracturing Materials; What Can We Control During a Fracture Treatment?; Why cause and effect with respect to production are not always obvious; Key Considerations for Hydraulic Fracturing of Gas Shales; Why We Fracture Shale Gas Wells…!; The Hydraulic Fracturing Processes; Functions of the Fracturing Fluid; Fracturing Challenges in Unconventional Gas Reservoirs; Post Fracture Treatment Monitoring Methods; Fracture Treatment Validation Via Microseismic Monitoring
Overview of Reservoir Simulation by Prem Dayal Saini
Reservoir simulation is the study of how fluids flow in a hydrocarbon reservoir when put under production conditions. The purpose is usually to predict the behavior of a reservoir to different production scenarios, or to increase the understanding of its geological properties by comparing known behavior to a simulation using different geological representations.
Production decline analysis is a traditional means of identifying well production problems and predicting well performance and life based on real production data. It uses empirical decline models that have little fundamental justifications. These models include
•
Exponential decline (constant fractional decline)
•
Harmonic decline, and
•
Hyperbolic decline.
This Training include several parts of Oil & Gas Engineering:
Petroleum Geology
Process Presentation
Utilities in an Oil & Gas Field
Process Engineering
Safety Engineering
Mechanical Engineering
Civil Engineering
Control & Instrumentation Engineering
Electrical Engineering
Design Engineering - 3D Model
Field Engineering
Commissioning & Startup
For more détails, please contact: Ramzi Fathallah
https://www.linkedin.com/in/ramzi-fathallah-a3762b85?trk=nav_responsive_tab_profile
This document provides a basic overview of the fundamental rock properties. It delivers a detailed analysis of the basic reservoir rock properties like porosity, permeability, Fluid saturation , wettability, etc.
Heavy Oil recovery traditionally starts with depletion drive and (natural) waterdrive with very low recoveries as a result. As EOR technique, steam injection has been matured since the 1950s using CSS (cyclic steam stimulation), steam drive or steam flooding, and SAGD (steam assisted gravity drainage). The high energy cost of heating up the oil bearing formation to steam temperature and the associated high CO2 footprint make steam based technology less attractive today and many companies in the industry have been actively trying to find alternatives or improvements. As a result there are now many more energy efficient recovery technologies that can unlock heavy oil resources compared with only a decade ago. This presentation will discuss breakthrough alternatives to steam based recovery as well as incremental improvement options to steam injection techniques. The key message is the importance to consider these techniques because steam injection is costly and has a high CO2 footprint
Johan van Dorp holds an MSc in Experimental Physics from Utrecht University and joined Shell in 1981. He has served on several international assignments, mainly in petroleum and reservoir engineering roles. He recently led the extra heavy-oil research team at the Shell Technology Centre in Calgary, focusing on improved in-situ heavy-oil recovery technologies. Van Dorp also was Shell Group Principal Technical Expert in Thermal EOR and has been involved with most thermal projects in Shell throughout the world, including in California, Oman, the Netherlands, and Canada. He retired from Shell after more than 35 years in Oct 2016. Van Dorp (co-)authored 13 SPE papers on diverse subjects.
Streamline based history matching of arrival times and bottom-hole pressure d...Shusei Tanaka
Streamline-based history matching techniques have provided significant capabilities in integrating field-scale water-cut and tracer data into high resolution geologic models. The effectiveness of the streamline approach lies in the fact that parameter sensitivities can be computed analytically as one-dimensional integrals along streamlines and requires little additional computational overhead beyond the forward simulation. However, application of the streamline-based approach for simultaneous integration of water-cut and bottomhole pressure has been rather limited. This is partly because the convective streamlines appear to offer no particular advantage while computing parameter sensitivities for the bottomhole pressure data. This limits the utility of streamline-based history matching particularly for three-phase black-oil and compositional systems where the integration of pressure data is a requirement to accurately model reservoir depletion mechanisms.
If you are looking GATE 2017 Question and Detailed Solution for Chemical Engineering(CH). Visit here http://www.engineersinstitute.com/pdf/gate-2017-detailed-solution-chemical-engineering-ch.pdf to completed detailed solution for CH.
If you are looking GATE 2017 Question and Detailed Solution for Chemical Engineering(CH). Visit here http://www.engineersinstitute.com/pdf/gate-2017-detailed-solution-chemical-engineering-ch.pdf to completed detailed solution for CH.
An effective reservoir management by streamline based simulation, history mat...Shusei Tanaka
The use of the streamline-based method for reservoir management is receiving increased interest in recent years because of its computational advantages and intuitive appeal for reservoir simulation, history matching and rate allocation optimization. Streamline-based method uses snapshots of flow path of convective flow. Previous studies proved its applicability for convection dominated process such as waterflooding and tracer transport. However, for a case with gas injection with strong capillarity and gravity effects, the streamline-based method tends to lose its advantages for reservoir simulation and may result in loss of accuracy and applicability for history-matching and optimization problems.
In this study, we first present the development of a 3D 3-phase black oil and compositional streamline simulator. Then, we introduce a novel approach to incorporate capillary and gravity effects via orthogonal projection method. The novel aspect of our approach is the ability to incorporate transverse effects into streamline simulation without adversely affecting its computational efficiency. We demonstrate our proposed method for various cases, including CO2 injection scenario. The streamline model is shown to be particularly effective to examine and visualize the interactions between heterogeneity which resulting impact on the vertical and areal sweep efficiencies.
Next, we apply the streamline simulator to history matching and rate optimization problems. In the conventional approach of streamline-based history matching, the objective is to match flow rate history, assuming that reservoir energy was matched already, such as pressure distribution. The proposed approach incorporates pressure information as well as production flow rates, aiming that reservoir energy are also reproduced during production rate matching.
Finally, we develop an NPV-based optimization method using streamline-based rate reallocation algorithm. The NPV is calculated along streamline and used to generate diagnostic plots of the effectiveness of wells. The rate is updated to maximize the field NPV. The proposed approach avoids the use of complex optimization tools. Instead, we emphasize the visual and the intuitive appeal of streamline methods and utilize flow diagnostic plots for optimal rate allocation.
We concluded that our proposed approach of streamline-based simulation, inversion and optimization algorithm improves computational efficiency and accuracy of the solution, which leads to a highly effective reservoir management tool that satisfies industry demands.
Quantitative Methods for Strategic Investment Planning in the Oil-Refining In...Brenno Menezes
Unlike traditional process design scenario-based methodologies to construct complex oil-refinery process network, discrete optimization approaches in MINLP and in an iterative MILP+NLP solve the capital investment planning problem to predict unit capacity increments (expansion or installation) for an integrated multi-site refinery problem considering resources such as capital and raw/intermediate material, processing and blending capabilities, market demands and project constraints.
Absorption of CO2 gas from CO
2/Air mixture into aqueous sodium hydroxide solution has been
achieved using packed column in pilot scale at constant temperature (T) of 25±1℃.The aim of the present work
was to improve the Absorption rate of this process, to find the optimal operation conditions, and to contribute to
the using of this process in the chemical industry. Absorption rate (RA) was measured by using different
operating parameters: gas mixture flow rate (G) of 360 -540 m3/h, carbon dioxide inlet concentration (CCO
2) of
0.1-0.5 vol. %, NaOH solution concentration (CNaOH) of 1-2 M, and liquid holdup in the column (VL) of 0.022-0.028 m3 according to experimental design. The measured RA was in the range of RA = 3.235 – 22.340 k-mol/h.
Computer program (Statgraphics/Experimental Design) was used to estimate the fitted linear model of RA in
terms of (G, CCO2, CNaOH, and VL), and the economic aspects of the process. R -squared of RA model was
91.7659 percent, while the standard error of the estimate shows the standard deviation of the residuals to be
1.7619. The linear model of RA was adequate, the operating parameters were significant except the liquid holdup
was not significant, and the interactions were negligible.
Welcome to WIPAC Monthly the magazine brought to you by the LinkedIn Group Water Industry Process Automation & Control.
In this month's edition, along with this month's industry news to celebrate the 13 years since the group was created we have articles including
A case study of the used of Advanced Process Control at the Wastewater Treatment works at Lleida in Spain
A look back on an article on smart wastewater networks in order to see how the industry has measured up in the interim around the adoption of Digital Transformation in the Water Industry.
6th International Conference on Machine Learning & Applications (CMLA 2024)ClaraZara1
6th International Conference on Machine Learning & Applications (CMLA 2024) will provide an excellent international forum for sharing knowledge and results in theory, methodology and applications of on Machine Learning & Applications.
Hierarchical Digital Twin of a Naval Power SystemKerry Sado
A hierarchical digital twin of a Naval DC power system has been developed and experimentally verified. Similar to other state-of-the-art digital twins, this technology creates a digital replica of the physical system executed in real-time or faster, which can modify hardware controls. However, its advantage stems from distributing computational efforts by utilizing a hierarchical structure composed of lower-level digital twin blocks and a higher-level system digital twin. Each digital twin block is associated with a physical subsystem of the hardware and communicates with a singular system digital twin, which creates a system-level response. By extracting information from each level of the hierarchy, power system controls of the hardware were reconfigured autonomously. This hierarchical digital twin development offers several advantages over other digital twins, particularly in the field of naval power systems. The hierarchical structure allows for greater computational efficiency and scalability while the ability to autonomously reconfigure hardware controls offers increased flexibility and responsiveness. The hierarchical decomposition and models utilized were well aligned with the physical twin, as indicated by the maximum deviations between the developed digital twin hierarchy and the hardware.
CW RADAR, FMCW RADAR, FMCW ALTIMETER, AND THEIR PARAMETERSveerababupersonal22
It consists of cw radar and fmcw radar ,range measurement,if amplifier and fmcw altimeterThe CW radar operates using continuous wave transmission, while the FMCW radar employs frequency-modulated continuous wave technology. Range measurement is a crucial aspect of radar systems, providing information about the distance to a target. The IF amplifier plays a key role in signal processing, amplifying intermediate frequency signals for further analysis. The FMCW altimeter utilizes frequency-modulated continuous wave technology to accurately measure altitude above a reference point.
HEAP SORT ILLUSTRATED WITH HEAPIFY, BUILD HEAP FOR DYNAMIC ARRAYS.
Heap sort is a comparison-based sorting technique based on Binary Heap data structure. It is similar to the selection sort where we first find the minimum element and place the minimum element at the beginning. Repeat the same process for the remaining elements.
Immunizing Image Classifiers Against Localized Adversary Attacksgerogepatton
This paper addresses the vulnerability of deep learning models, particularly convolutional neural networks
(CNN)s, to adversarial attacks and presents a proactive training technique designed to counter them. We
introduce a novel volumization algorithm, which transforms 2D images into 3D volumetric representations.
When combined with 3D convolution and deep curriculum learning optimization (CLO), itsignificantly improves
the immunity of models against localized universal attacks by up to 40%. We evaluate our proposed approach
using contemporary CNN architectures and the modified Canadian Institute for Advanced Research (CIFAR-10
and CIFAR-100) and ImageNet Large Scale Visual Recognition Challenge (ILSVRC12) datasets, showcasing
accuracy improvements over previous techniques. The results indicate that the combination of the volumetric
input and curriculum learning holds significant promise for mitigating adversarial attacks without necessitating
adversary training.
NUMERICAL SIMULATIONS OF HEAT AND MASS TRANSFER IN CONDENSING HEAT EXCHANGERS...ssuser7dcef0
Power plants release a large amount of water vapor into the
atmosphere through the stack. The flue gas can be a potential
source for obtaining much needed cooling water for a power
plant. If a power plant could recover and reuse a portion of this
moisture, it could reduce its total cooling water intake
requirement. One of the most practical way to recover water
from flue gas is to use a condensing heat exchanger. The power
plant could also recover latent heat due to condensation as well
as sensible heat due to lowering the flue gas exit temperature.
Additionally, harmful acids released from the stack can be
reduced in a condensing heat exchanger by acid condensation. reduced in a condensing heat exchanger by acid condensation.
Condensation of vapors in flue gas is a complicated
phenomenon since heat and mass transfer of water vapor and
various acids simultaneously occur in the presence of noncondensable
gases such as nitrogen and oxygen. Design of a
condenser depends on the knowledge and understanding of the
heat and mass transfer processes. A computer program for
numerical simulations of water (H2O) and sulfuric acid (H2SO4)
condensation in a flue gas condensing heat exchanger was
developed using MATLAB. Governing equations based on
mass and energy balances for the system were derived to
predict variables such as flue gas exit temperature, cooling
water outlet temperature, mole fraction and condensation rates
of water and sulfuric acid vapors. The equations were solved
using an iterative solution technique with calculations of heat
and mass transfer coefficients and physical properties.
Student information management system project report ii.pdfKamal Acharya
Our project explains about the student management. This project mainly explains the various actions related to student details. This project shows some ease in adding, editing and deleting the student details. It also provides a less time consuming process for viewing, adding, editing and deleting the marks of the students.
2. Applied Reservoir Engineering : Dr. Hamid Khattab
Reservoir DefinitionReservoir DefinitionReservoir DefinitionReservoir Definition
Cap rock
Res. Fluid
Reservoir rock
R iReservoir
Shallow Deep
offshare onshare offshare onshare
4. Applied Reservoir Engineering : Dr. Hamid Khattab
Rock Properties
Porosity Saturation Permeability Capillary Wettability
Absolute Effective
So
Sw
Sg
Absolute
Eff ti
Relative
Primary Primary
Effective
Ratio
Secondary Seccondary
5. Applied Reservoir Engineering : Dr. Hamid Khattab
Reservoir fluidsReservoir fluids
Water Oil Gas
Salt Fresh
Black
Volatile
Drey
Wet Condensate
Low volatile
High volatile Ideal
Real
(non ideal)
6. Applied Reservoir Engineering : Dr. Hamid Khattab
Fluid properties
Gas Oil Water
AM T P Z C βρg AMw γg Tc PC Z Cg βg µg βw rs µw SalinityCw
ρo γo APT rs βo βt µo Co
TR PR
7. Applied Reservoir Engineering : Dr. Hamid Khattab
Applied reservoir Engineering ContentsApplied reservoir Engineering Contents
1. Calculation of original hydrocarbon in place
i. Volumetric methodi. Volumetric method
ii. Material balance equation (MBE)
2 Determination of the reservoir drive mechanism2. Determination of the reservoir drive mechanism
– Undersaturated
– Depletion
– Gas cap
– Water drive
– Combination
3. Prediction of future reservoir performance
– Primary recoveryPrimary recovery
– Secoundry recovery by : Gas injection
Water injection
8. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of original hydrocarbon in place byCalculation of original hydrocarbon in place byCalculation of original hydrocarbon in place byCalculation of original hydrocarbon in place by
volumetric methodvolumetric method
● ●
6
7
Well Depth
1 D1
●
●
●4
3
2
1 D1
2 D2
3 D3
4 D4
●
●
●
●
1
9
4 D4
5 D5
6 D6
7 D
●8
5
9
Scale:1:50000
7 D7
8 D8
9 D9
Location map
Structural contour map
9. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of original hydrocarbon in place byCalculation of original hydrocarbon in place byCalculation of original hydrocarbon in place byCalculation of original hydrocarbon in place by
volumetric methodvolumetric method
Well Depth
1 h1
G
1 h1
2 h2
3 h3
4 h4
Goc
Gas
Oil4 h4
5 h5
6 h6
7 h
Woc
Oil
Water
7 h7
8 h8
9 h9
30
10
0
Isopach map
10. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of original hydrocarbon in place byCalculation of original hydrocarbon in place byCalculation of original hydrocarbon in place byCalculation of original hydrocarbon in place by
volumetric methodvolumetric method
)1(. wiSBVN −= φ
)1()( wiSAh −= φ )()( wiφ
wiSAh
β
φ
6155
)1(43560 −
= SCFBblgβ
oiβ615.5
wiSAh
N
φ )1(7758 − STB
STBbbloβ
acresA:
oi
wi
N
β
φ )(
=
iSAhφ )1(7758 −
STB
SCF
fth :
fractionsSwi :,φ
gi
wiSAh
G
β
φ )1(7758
=
SCF fwi,φ
11. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of (BV) using isopach mapCalculation of (BV) using isopach map
Area inch2C.L
( ) g p p( ) g p p
1. Trapozoidal method:
A110
Ao0 WOC
5.01 >−nn AA
A330
A220
[ ]AAAAA
h
BV nn +++++= − 22......22
2
1210
A550
A440
A’GOC
[ ]
[ ]AA
h
n
nn
′+
′
+
2
2
1210
A770
A660
O76
A770
12. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of (BV) using isopach mapCalculation of (BV) using isopach map
Area inch2C.L
( ) g p p( ) g p p
2. Pyramid or cone method
5.01 ≤−nn AA A110
Ao0 WOC
[ ]AAAA
h
BV .
3
1010 ++=
A330
A220
[ ]AAAA
h
.
3
2121 +++
A550
A440
A’GOC
[ ] [ ]nnnn A
h
AAAnA
h
3
.
3
11 ++++ −−
A770
A660
O76
A770
13. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of (BV) using isopach mapCalculation of (BV) using isopach map( ) g p p( ) g p p
3. Simpson method
Odd number of contour lines
[ ]nn AAAAAA
h
BV 24......424
3
13210 ++++++= −
[ ]nA
h
3
3
′
+
3
14. Applied Reservoir Engineering : Dr. Hamid Khattab
Converting map areas (inchConverting map areas (inch22) to acres) to acresConverting map areas (inchConverting map areas (inch22) to acres) to acres
Say : Scale 1 : 50000Say : Scale 1 : 50000
1 inch = 50,000 inch
acres56398
(50,000)
inch1
2
2
acres56.398
43560144
( )
inch1 =
×
=
15. Applied Reservoir Engineering : Dr. Hamid Khattab
Converting map areas (inchConverting map areas (inch22) to acres) to acres
Example 1 :
Converting map areas (inchConverting map areas (inch22) to acres) to acres
Gi th f ll i l i t d f it fGiven the following planimetred areas of an oit of
reservoir. Calculate the original oil place (N) if φ =25%,
Swi=30%, βoi=1.4 bbl/STB and map scale=1:15000
C.L : 0 10 20 30 40 50 60 70 80 86
Area inch2 : 250 200 140 98 76 40 26 12 5 0
16. Applied Reservoir Engineering : Dr. Hamid Khattab
Converting map areas (inchConverting map areas (inch22) to acres) to acresConverting map areas (inchConverting map areas (inch22) to acres) to acres
Solution :
[ ]
[ ] [ ] [ ]050050
6
512512
10
12261226
10
2640276298214022002250
2
10
+×+×+×+×+×+=BV
[ ] [ ] [ ]050050
3
6
512512
3
10
12261226
2
10
×+++×+++×+++
ftinch :7198 2
=
acres87.35
43560144
(15,000)
inch1
2
2
=
×
=
ftinch :7198
acresBV 39.25819387.357198 =×=∴
MMSTBN 38.250
4.1
)3.01(25.039.2581937758
=
−×××
=∴
17. Applied Reservoir Engineering : Dr. Hamid Khattab
Converting map areas (inchConverting map areas (inch22) to acres) to acres
By using Simpson method
Converting map areas (inchConverting map areas (inch22) to acres) to acres
[ ]
[ ]0505
6
5212426240476298414022004250
3
10
×+++
×+×+×+×+×+×+×+×+=BV
[ ]0505
3
×+++
ftinch .6.7156 2
=
ftacro
f
.6.25670987.356.7156 =×=
)301(25062567097758
MMSTBN 94.248
4.1
)3.01(25.06.2567097758
=
−×××
=∴
MMSTBNav 66.2492)94.24838.250( =+=∴
18. Applied Reservoir Engineering : Dr. Hamid Khattab
Converting map areas (inchConverting map areas (inch22) to acres) to acres
Example 2 :
If th i f l 1 i i d
Converting map areas (inchConverting map areas (inch22) to acres) to acres
If the reservoir of example 1 is a gas reservoir and
βg=0.001 bbl/SCF. Calculate the original gas in place
S l tiSolution :
)301(250392581937758 −×××
MMSCFG 53.350
001.0
)3.01(25.039.2581937758
=
×××
=
19. Applied Reservoir Engineering : Dr. Hamid Khattab
Converting map areas (inchConverting map areas (inch22) to acres) to acres
Example 3 :
Converting map areas (inchConverting map areas (inch22) to acres) to acres
A gas cap has the following data : φ =25%, Swi=30%, βoi=1.3
bbl/STB, βgi=0.001 bbl/SCF and map scale=1:20000
C.L : 0(WOC) 10 20 30 33(GOC) 40 50 60 70 76
Area inch2 : 350 310 270 220 200 190 130 55 25 0
Calculate the original oil in place (N) and the original gas in
place (G)
21. Applied Reservoir Engineering : Dr. Hamid Khattab
Reservoir drive mechanismReservoir drive mechanismReservoir drive mechanismReservoir drive mechanism
Water reservoirWater reservoir
P
Gas reservoir
Gas
GasBg
Water
with bottom
water drive
without bottom
water drive
g
Oil reservoir
22. Applied Reservoir Engineering : Dr. Hamid Khattab
Oil reservoir
Undersaturated
P>Pb
OilOil
Oil
Water
with bottomwithout bottom Saturated
water drive
without bottom
water drive
Saturated
P≤Pb
Oil
Oil
Oil
Oil
W
Gas
Gas
Gas
Oil
Water
Gas
Combination
drive
Bottom water
drive
Gas cap
drive
Depletion
drive
23. Applied Reservoir Engineering : Dr. Hamid Khattab
PVT data for gas and oil reservoirsPVT data for gas and oil reservoirsPVT data for gas and oil reservoirsPVT data for gas and oil reservoirs
Gas reservoirs
Bg
Gas reservoirs
P
ZT
Bg 00504.0=
P
24. Applied Reservoir Engineering : Dr. Hamid Khattab
PVT data for gas and oil reservoirsPVT data for gas and oil reservoirs
Saturated oil reservoirs
PVT data for gas and oil reservoirsPVT data for gas and oil reservoirs
Boi=Bti
µo
B
rsi
Bt = Bo+(rsi-rs)Bg
P
ZT
Bg 00504.0=
Bo
rs
Boi= Bti
P
Bg
0
1
P0 Pi
25. Applied Reservoir Engineering : Dr. Hamid Khattab
PVT data for gas and oil reservoirsPVT data for gas and oil reservoirsPVT data for gas and oil reservoirsPVT data for gas and oil reservoirs
Undersaturated oil reservoirs
saturated undersat.
P1 > Pb
Bt
µo
rsi=c
Bo
rs
Bg
1
0
26. Applied Reservoir Engineering : Dr. Hamid Khattab
Laboratory measurment of PVT dataLaboratory measurment of PVT dataLaboratory measurment of PVT dataLaboratory measurment of PVT data
GasGas
SCF
Oil
P
Oil
Oil
P
OilOil
SCF
STB
undersaturatedsaturated
Pb P > Pb Pi
P = 14.7 psi
T = 60o F
27. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of original gas in place by MBECalculation of original gas in place by MBECalculation of original gas in place by MBECalculation of original gas in place by MBE
1. Gas reservoir without bottom water drive
pG
T∆ ( ) gip BGG −giGB
( )
ipp∠ip
gp BG
G =∴
( ) gpgi BGGGB −=
1
gig BB
G
−
=∴ 1
28. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of original gas in place by MBECalculation of original gas in place by MBECalculation of original gas in place by MBECalculation of original gas in place by MBE
1. Gas reservoir without bottom water drive
Example 4 :
psiP SCFG p SCFbblgB Z G
201.60.810.00084123900
0x1060.830.000770x10-64000
p
G
195.20.770.00095373700
200.20.790.00089273800 .constG ≠
Solution :
199.70.750.00107583600
Using eq. (1)
29. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of original gas in place by MBECalculation of original gas in place by MBECalculation of original gas in place by MBECalculation of original gas in place by MBE
MBE as an equation of a straight line
y1
( ) gpgi BGGGB −=
( )BBGBG∴ 2
gp BG
G
y1
( )giggp BBGBG −=∴
Another form:
2
gig BB −
x1
( )
−=
i
p
p
TZ
p
ZT
G
p
ZT
G 00504.000504.0 Z
Gp
y2
i
p
ppp
−=∴ iZZ
GG
Z
3
p
p
G
=∴
i
p
pp
GG
p 3
ii PZpZ −
x2
30. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of original gas in place by MBECalculation of original gas in place by MBECalculation of original gas in place by MBECalculation of original gas in place by MBE
Another form:
( ) gpgi BGGGB −=
( ) ZZ
p
i
i
Z
p
( )
−=
p
Z
GGG
p
Z
p
i
i
00504.000504.0
pGP
Z
y3 i
i
GZ
p
ppp
i
ip
Z
p
G
G
Z
P
−=∴ 1
G
p
i
i
i
i
G
GZ
p
Z
p
Z
p
−=∴
at pG
x3
G
0
0=
Z
p
pGG =
p
31. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of original gas in place by MBECalculation of original gas in place by MBE
Example 5 :
Calculation of original gas in place by MBECalculation of original gas in place by MBE
Solve the previous example using MBE as a straigh line
Solution :
p PZ ii PZpZ −gp BGgig BB − ZP pG
1244411.752.251.0680.000053900
0x10-64819― x10-52.075x10-4―x104―4000
3738965.912.663.5150.000183700
2741773.152.392.4030.000123800
x3y3x2y2y1x1
5634218.092.885.9900.000303600
From Figgers STBG 6
10200×=
32. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of original gas in place by MBECalculation of original gas in place by MBE
2.Gas reservoir with bottom water drive
Calculation of original gas in place by MBECalculation of original gas in place by MBE
R
pG
pW
T∆
∴
Assuming =0 causes an increase in G continuously
33. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of original gas in place by MBECalculation of original gas in place by MBE
MBE as a straight line
Calculation of original gas in place by MBECalculation of original gas in place by MBE
F/
45o
∴
N
∴
/
Assuming is known
33
34. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of original gas in place by MBECalculation of original gas in place by MBE
A i i h k b d i h h f ll i
Calculation of original gas in place by MBECalculation of original gas in place by MBE
Example 6 :
A gas reservoir with a known bottom water drive has the following
data: =0 and
B
0x10-60.000930x10940000
We bblT years psiP SCFG p SCFbblgB
7.4900.0010772.3338002
2.2970.0009827.8539001
13.3080.00117113.8537003
18.4860.00125151.4836004
34
Calculate the original gas in place
35. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of original gas in place by MBECalculation of original gas in place by MBE
Tyear F Eg F/Eg x109 We/Eg x109
Solution
Calculation of original gas in place by MBECalculation of original gas in place by MBE
Tyear F Eg F/Eg x10 We/Eg x10
1 27.2x106 0.00005 546 45.93
2 77.39 0.00014 553 53.04
3 133.20 0.00024 555 55.44
4 189.35 0.00032 554 54.25
F/EF/E
g
45
From Fig: G=500x109 SCF
G=500x109
We/Eg
36. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of original gas in place by MBECalculation of original gas in place by MBE
Gas Cap Expansion an Shrinkage
G
Calculation of original gas in place by MBECalculation of original gas in place by MBE
Gpc
gas
GOC
Gpc
expansion
GOC
GOC
Oil
shrinkage
Oil
Shrinkage due to: poor planning or accident and corrosiong p p g
- Assume gas cap expansion = (G-Gpc).Bg-GBgi
Assume gas cap shrinkage = GB (G Gp )B- Assume gas cap shrinkage = GBgi - (G-Gpc)Bg
Gpc: gas produced from the gas cap and my be = zero
37. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of original gas in place by MBECalculation of original gas in place by MBE
Example: 7
Calculation of original gas in place by MBECalculation of original gas in place by MBE
Calculate the gas cap volume change if G=40x109 SCF
P Gpc x109 Bg
4000 0 0.0020
3900 4 0 00223900 4 0.0022
3800 7 0.0025
3700 10 0.0028
3600 13 0.0031
3500 17 0.0035
38. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of original gas in place by MBECalculation of original gas in place by MBE
Solution
Calculation of original gas in place by MBECalculation of original gas in place by MBE
Assuming gas cap expansion = (G-Gpc).Bg-Ggi
Pressure Gas cap change x103 type
4000 - -
3900 -800 shrinkage
3800 +2500 expansion3800 +2500 expansion
3700 +4000 expansion
3600 +3700 shrinkage
3500 +5000 expansion
Shrinkage at P=3600 may be due PVT or Gp dataShrinkage at P=3600 may be due PVT or Gpc data
39. Applied Reservoir Engineering : Dr. Hamid Khattab
C l l ti f i i l il i l b MBEC l l ti f i i l il i l b MBECalculation of original oil in place by MBECalculation of original oil in place by MBE
a) Under-saturated oil reservoirs
Characteristics
P>P- P>Pb
- No free gas, no Wp
- Large volume
Limited K- Limited K
- Low flow rate
- Produce by Cw and Cf
40. Applied Reservoir Engineering : Dr. Hamid Khattab
C l l ti f i i l il i l b MBEC l l ti f i i l il i l b MBE
1- Under-saturated oil reservoirs without bottom water
Calculation of original oil in place by MBECalculation of original oil in place by MBE
Np
NBoi
P P
(N-Ni)Bo
P>PPi>Pb
P>Pb
neglecing Cw and Cf
NBoi=(N-Np)Bo
op BN
N∴ (1)
oio
p
BB
N
−
=∴ (1)
41. Applied Reservoir Engineering : Dr. Hamid Khattab
C l l ti f i i l il i l b MBEC l l ti f i i l il i l b MBE
Example: 8
C l l t th i i l il i l i t d i d l ti C
Calculation of original oil in place by MBECalculation of original oil in place by MBE
Calculate the original oil in place assuming no water drive and neglecting Cw
and Cf using the following data
P Np x106 Bo
4000 0 1.40
3800 1 535 1 423800 1.535 1.42
3600 3.696 1.45
3400 7.644 1.49
3200 9.545 1.54
42. Applied Reservoir Engineering : Dr. Hamid Khattab
C l l ti f i i l il i l b MBEC l l ti f i i l il i l b MBE
Solution
Pressure NpBo x106 Bo-Boi N x106
Calculation of original oil in place by MBECalculation of original oil in place by MBE
4000 - - -
3800 2.179 0.02 108.95
3600 5 539 0 05 110 78 constN ≠3600 5.539 0.05 110.78
3400 11.389 0.09 126.64
3200 14.699 0.14 104.99
rearrange MBE as a straight line
NBoi = (N-Np)Bo
F
F = NEo
From Fig:
6
N
STBxN 6
10110≠
Eo
43. Applied Reservoir Engineering : Dr. Hamid Khattab
C l l ti f i i l il i l b MBEC l l ti f i i l il i l b MBE
o.b.p=1 psi/ftD
Considering Cw and Cf
Calculation of original oil in place by MBECalculation of original oil in place by MBE
- overburden pressure = 1 psi/ftD
- rock strength = 0.5 psi/ftD
r s rv ir pr ssur 0 5 psi/ftD- reservoir pressure = 0.5 psi/ftD
o.b.p
44. Applied Reservoir Engineering : Dr. Hamid Khattab
C l l ti f i i l il i l b MBEC l l ti f i i l il i l b MBECalculation of original oil in place by MBECalculation of original oil in place by MBE
Considering Cw and Cf
NBoi
VpBNNNB fwopoi ∆+−= )( ,
Pi>Pb
dpVCdVp
dVp
C
VpVpVp
f
fwfw
→
∆+∆=∆
1
,
(N-Np)Bo
dVp
dpVCdVp
dpV
C pff
f
p
f =→=
1
.
P>Pb
∆Vp,,w
V
dpVCdVp
dp
dVp
V
C www
w
w
w =→= .
1
dpVSCdVpVSV
V
V
S pwwwpww
p
w
w =→=→=
45. Applied Reservoir Engineering : Dr. Hamid Khattab
C l l ti f i i l il i l b MBEC l l ti f i i l il i l b MBECalculation of original oil in place by MBECalculation of original oil in place by MBE
Considering Cw and Cf
dpVCSCdVp pfwwwf +=∴ )(,
S
NB
VpSVpNB
w
oi
woi
−
=→−=
)1(
)1(
dpNB
S
CSC
dVp oi
fww
wf
−
+
=∴ )
1
(,
pNB
S
CSC
BNNNB
S
oi
fww
opoi
w
∆
+
+−=∴ )
1
()(
1
S
oi
w
opoi
−1
46. Applied Reservoir Engineering : Dr. Hamid Khattab
C l l ti f i i l il i l b MBEC l l ti f i i l il i l b MBE
BN
N
op
Calculation of original oil in place by MBECalculation of original oil in place by MBE
Considering Cw and Cf
BB
pB
S
CSC
BB
N
oi
w
fww
oio
op
∆
−
+
+−
=∴
)
1
(
BNBN
N
pBCBB
pB
BB
C
opop
oiooio
oi
oio
o
==∴
∆=−→
∆
−
=Q
SSwhere
pB
S
CSC
S
SC
pB
S
CSC
C
N
wo
oi
w
fww
w
oo
oi
w
fww
o
−=
∆
−
+
+
−
∆
−
+
+
∴
1
]
11
[]
1
[
pB
S
CSCSC
BN
N
oi
fwwoo
op
wo
∆
++
=∴
]
1
[
pCB
BN
N
S
eoi
op
w
∆
=
−1
(2)
47. Applied Reservoir Engineering : Dr. Hamid Khattab
C l l ti f i i l il i l b MBEC l l ti f i i l il i l b MBECalculation of original oil in place by MBECalculation of original oil in place by MBE
Considering Cw and Cf
PPP i −=∆
Pi
Pi
VV
dP
dV
V
C
oi
o −=
1
.
1
PB
BB
C
oi
oio
o
∆
−
=
Pi
BB
PP
VV
V
oio
i
i
oi
−
−
−
=
)(1
.
1
Voi
Vo
PB
oio
oi ∆
=
)(
.
)salinityand,,(
)(
sw
f
rTPfC
fC
=
= φ
From the following charts
48. Applied Reservoir Engineering : Dr. Hamid Khattab
C l l ti f i i l il i l b MBEC l l ti f i i l il i l b MBECalculation of original oil in place by MBECalculation of original oil in place by MBE
49. Applied Reservoir Engineering : Dr. Hamid Khattab
C l l ti f i i l il i l b MBEC l l ti f i i l il i l b MBE
Example: 9
l l ( ) d h ff f d
Calculation of original oil in place by MBECalculation of original oil in place by MBE
Solution
Solve example (8) considering the effect of Cw and Cf
R1(Fig 2)r (Fig 1)C (Fig 4)∆P=(Pi P)P
BB
C oio −
=
182.9x10-6――4000
R1(Fig.2)rsf(Fig.1)Cwp(Fig.4)∆P=(Pi-P)P
pB
C
oi
o
∆
=
0.8516.82.958.9284003600
17.22.937.143x10-52003800
15.23.0012.5008003200
162.9810.7146003400
50. Applied Reservoir Engineering : Dr. Hamid Khattab
C l l ti f i i l il i l b MBEC l l ti f i i l il i l b MBE
Continue
Calculation of original oil in place by MBECalculation of original oil in place by MBE
Cw=CwpxR2R2 (Fig.3)rs= rsf x R1P
w
fwwoo
S
CSCSC
−
++
1
7.725x10-53.3111.1314.623800
―3.30x10-61.415.34000
13.5693.2891.10413.602400
9.5703.2471.1114.283600
13.1433.171.0912.923200
51. Applied Reservoir Engineering : Dr. Hamid Khattab
C l l ti f i i l il i l b MBEC l l ti f i i l il i l b MBE
Continue
BN
Calculation of original oil in place by MBECalculation of original oil in place by MBE
pCB
BN
N
eoi
op
∆
=
P NpBo NBoiCe∆P N
4000 ― ― ―
3800 2.179x016 0.0218 108.2x106
3600 5.359 0.0536 107.9
N ≠ C
3400 11.389 0.1131 106.5
3200 14 699 0 1470 105 13200 14.699 0.1470 105.1
52. Applied Reservoir Engineering : Dr. Hamid Khattab
C l l ti f i i l il i l b MBEC l l ti f i i l il i l b MBE
Use MBE as a straight line as follows:
Calculation of original oil in place by MBECalculation of original oil in place by MBE
PCNBBN eoiop ∆=
BNF
Plot the fig
oNEF = op BNF =
6
10100×=NPlot the fig. 10100×=N
STBN 6
10100×=
PCBE ∆PCBE eoio ∆=
53. Applied Reservoir Engineering : Dr. Hamid Khattab
U d t t d il i ith b tt tU d t t d il i ith b tt tUndersaturated oil reservoir with bottom waterUndersaturated oil reservoir with bottom water
pN
pW pW
(N-Np)Bo
NBoi
P>PbPi>Pb
Assuming (We) is known and neglect Cw+Cf
( ) ( )BwWBNNNB −+−= ( ) ( )
( )
i
wpeop
wpeopoi
BB
BwWBN
N
BwWBNNNB
−
−−
=∴
+=
oio BB
Assuming We=0 will cuse an increase in (N)
54. Applied Reservoir Engineering : Dr. Hamid Khattab
U d t t d il i ith b tt tU d t t d il i ith b tt tUndersaturated oil reservoir with bottom waterUndersaturated oil reservoir with bottom water
Example 11 :
Using the following data in the undersaturated oil reservoir with a
known (We), neglecting Cw & Cf calculate (N): wp= 0
P Np Bo We
4000 ―x106 1.40 ―x106
3800 2.334 1.45 1.135
3600 5 362 1 42 2 4163600 5.362 1.42 2.416
3400 10.033 1.49 3.561
3200 12 682 1 54 4 8323200 12.682 1.54 4.832
55. Applied Reservoir Engineering : Dr. Hamid Khattab
U d t t d il i ith b tt tU d t t d il i ith b tt tUndersaturated oil reservoir with bottom waterUndersaturated oil reservoir with bottom water
Solution :Solution :
( )
oio
wpeop
BB
BwWBN
N
−
−−
=
P NpBo Bo-Boi N
4000 106 1064000 ―x106 ― ―x106
3800 3.314 0.02 108.5
3600 7 775 0 05 107 1 N ≠ C3600 7.775 0.05 107.1
3400 14.950 0.09 126.5
3200 19 531 0 14 105 0
N ≠ C
3200 19.531 0.14 105.0
56. Applied Reservoir Engineering : Dr. Hamid Khattab
U d t t d il i ith b tt tU d t t d il i ith b tt t
E
FRearrange MBE as a straight line
Undersaturated oil reservoir with bottom waterUndersaturated oil reservoir with bottom water
oE
o
45
[ ] eiowpop WBBNBWBN +−=+ 0
WENF +=
110=N
eo WENF +=
oeo EWNEF +=∴
oe EW
[ ]ioo BBE 0−= oe EWp oEFop BNF =[ ]ioo 0
48 32155 57 7750 053600
56.75165.73.3140.023800
― x10-6―― x10-6―4000
p p
34.51139.519.5310.143200
39.56166.414.9800.093400
48.32155.57.7750.053600
57. Applied Reservoir Engineering : Dr. Hamid Khattab
Undersaturated oil reservoir with bottom waterUndersaturated oil reservoir with bottom water
Example 11 :
Solve examole (10) considering Cw and Cf effect
Solution :So ut on
Cw, Co, Cf and Ce are the same as example (9)
Peoi
e
o
e
CB
W
E
W
∆
=PeoiCB ∆
Peoi
oP
o CB
BN
E
F
∆
=P∆eCP
45.07145.060.05364009.5703600
52.06 x106152.01 x1060.02182007.7853800
――――― x10-54000
32.87132.860.147080013.1433200
31.26131.250.113960013.5683400
45.07145.060.05364009.5703600
F
oE
F
o
45
Pi
ee
CB
W
E
W
∆
=
Pi
oP
CB
BN
E
F
∆
=Plot vs
6
10100 ×=N
oe EW
Peoio CBE ∆Peoio CBE ∆
As in Fig. 6
10100×=N
58. Applied Reservoir Engineering : Dr. Hamid Khattab
B S t t d il iB S t t d il iB. Saturated oil reservoirsB. Saturated oil reservoirs
1 D l ti d i i1. Depletion drive reservoirs
Characteristics
bPP ≤• b
0=• pW
rapidlyincreasesRp•
FRlow .•
59. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of original oil in place by MBECalculation of original oil in place by MBE
pG
pN
Calculation of original oil in place by MBECalculation of original oil in place by MBE
T∆oiNB ( ) op BNN −
p
Free gas
( )
bi PP≤
Free gas
p
( ) gasfreeBNNNB opoi +−=
( ) SCFRNrNNNrgasfree ppspsi −−−=
( ) ( )[ ] gppspsiopoi BRNrNNNrBNNNB −−−+−=∴
( )[ ]( )[ ]
( ) gssioio
gspop
BrrBB
BrRBN
N
−+−
−+
=∴
60. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of original oil in place by MBECalculation of original oil in place by MBE
Example 12 :
Calculation of original oil in place by MBECalculation of original oil in place by MBE
Calucaltion (N) for a depletion drive reservoir has the following data : Swi=30%
91 506140 0012731 4236743 873800
― x1067180.0010411.492718― x1064000
NrsBgBoRPNPP
ion
96.014000.0022001.28630776.443400
96.025100.0016271.35519375.263600
91.506140.0012731.4236743.873800
Solut
96.014000.0022001.28630776.443400
As shown N ≠ const., so rearrange MBE as a straight line
61. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of original oil in place by MBECalculation of original oil in place by MBE
( )[ ] ( )[ ]gssioiogspop BrrBBNBrRBN −+−=−+
Calculation of original oil in place by MBECalculation of original oil in place by MBE
oENF =
Solution :
P F Eo
4000 0 106 0
Solution
F
4000 0x106 0
3800 5.802 0.0634
3600 19 339 0 2014
6
1096×=N
3600 19.339 0.2014
3400 46.124 0.4804
6
oE
STBNFigFrom 6
1096: ×=
o
62. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of original oil in place by MBECalculation of original oil in place by MBE
( ) gssioiop BrrBBN
FR
−+−
Calculation of original oil in place by MBECalculation of original oil in place by MBE
( )
( ) gspo
gssioiop
BrRBN
FR
−+
==.
( )PRPfFR &. = ( )PRPfFR &.
PRFR 1. ∝
To increase R.F:
• Working over high producing GOR wellsWorking over high producing GOR wells
• Shut-in ,, ,, ,, ,, ,,
• Reduce (q) of ,, ,, ,, ,,
R i j t f d d• Reinject some of gas produced
63. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of original oil in place by MBECalculation of original oil in place by MBE
Example 13 :
For example 12 at P=3400 psi calculate: S and R F without Gi and
Calculation of original oil in place by MBECalculation of original oil in place by MBE
Solution :
For example 12, at P 3400 psi calculate: Sg and R.F without Gi and
with Gi=60 Gp
gasfree
S =
( )[ ]i BRNrNNNrgasfree −−−=
volumepore
S g =
( )[ ] gppspsi BRNrNNNrgasfree
( )
bbls6
6
66
1005.280022.0
30771044.6
4061044.6967181096
×=×
××
−××−−××
=
30771044.6
( )
bbls
S
NB
volumepore
w
oi 6
6
1062.204
3.01
492.11096
)1(
×=
−
××
=
−
=
( )w )(
%7.13137.0
1062.204
1005.28
6
6
==
×
×
=∴ gS
64. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of original oil in place by MBECalculation of original oil in place by MBE
( ) gssioio BrrBB
FR
−+−
Calculation of original oil in place by MBECalculation of original oil in place by MBE
( )
( ) gspo
gssioio
Gwithout
BrRB
FR i
−+
=.
( ) 0022.0406718492.1286.1 ×−+− ( )
( )
%7.6067.0
0022.04063077286.1
==
×−+
=
( )
( )
gssioio
Gwith
BrRB
BrrBB
FR i
−+
−+−
=%60.
( )
( ) 002204063077402861
0022.0406718492.1286.1
×−×+
×−+−
=
( ) gspo BrRB +
( )
%49.151549.0
0022.040630774.0286.1
==
××+
65. Applied Reservoir Engineering : Dr. Hamid Khattab
2 Gas Cap reservoir2 Gas Cap reservoir2. Gas Cap reservoir2. Gas Cap reservoir
Characteristics
• P falls slowly
• No Wp
• High GOR for high structure wells
• R.F > R.Fdepletion
• Ultimate R.F ∝ Kv, gas cap size, 1/µo, 1/qoUltimate R.F ∝ Kv, gas cap size, 1/µo, 1/qo
66. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of OOIP by MBECalculation of OOIP by MBEyy
pN
pG
giGB
(N-Np)Bo
free gas
oiNB
gi
oi
gi
NB
B
m =
( ) gasfreeBNNNBGB opoigi +−=+
P>PbiP
[ ] ( ) ppspsi RNrNNGNrgasfree −−−+=
( )[ ]gspop BrRBN
N
−+
=∴
( ) ( )gig
gi
oi
gssioio BB
B
B
mBrrBB
N
−+−+−
∴
( ) ( )oi
BRNNN
mNB
NBNNNBNB
+++∴ ( ) ( ) gppsp
gi
oi
siopoioi BRNrNN
B
NrpBNNNBmNB
−−−++−=+∴
This equation contains two unknown (m and N)
67. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of OOIP by MBECalculation of OOIP by MBEyy
Rearrange MBE to give a straight line equation
( )[ ] ( )[ ] ( )gig
oi
gssioiogspop BB
B
mNB
BrrBBNBrRBN −+−+−=−+ gg
gi
ggpp
B
E
F
go GENEF +=
oE
G
o
g
o E
E
GN
E
F
+=∴
NN
og EE
68. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of OOIP by MBECalculation of OOIP by MBEyy
Example 14 :
Calculate (N) and (m) for the following gas cap reservoir
P Np Rp Bo rs Bg
4000 ―x106 510 1.2511 510 0.00087
3900 3.295 1050 1.2353 477 0.00092
3800 5 905 1060 1 2222 450 0 000963800 5.905 1060 1.2222 450 0.00096
3700 8.852 1160 1.2122 425 0.00101
3600 11.503 1235 1.2022 401 0.00107
3500 14.513 1265 1.1922 375 0.00113
3400 17.730 1300 1.1822 352 0.00120
69. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of OOIP by MBECalculation of OOIP by MBEyy
Solution :
+=∴ g
E
E
GN
E
F
P F Eo Eg F/Eo Eg/Eo
+∴
oo E
GN
E
4000 ―x106 0 0 ―x106 ―
3900 5.807 0.0145 0.00005 398.8 0.0034
3800 10.671 0.0287 0.00009 371.8 0.0031
3700 17.302 0.0469 0.00014 368.5 0.0029
3600 24.094 0.0677 0.00020 355.7 0.0028
3500 31.898 0.09268 0.00026 340.6 0.0027
3400 41 130 0 1207 0 00033 340 7 0 00273400 41.130 0.1207 0.00033 340.7 0.0027
70. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of OOIP by MBECalculation of OOIP by MBEyy
F
oE
9
10826 ×=G
From Fig.
N = 115 x 106 STB
6
10115 ×=N 10115 ×N
og EE
2511110115 6
×××mmNB
00087.0
2511.110115
10826 9 ×××
==×=
m
B
mNB
G
gi
oi
50∴ 5.0=∴m
71. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of OOIP by MBECalculation of OOIP by MBEyy
Another solution
Assume several values of (m) until the straight line going
through the origin as follows:
go GENEF +=
mNB
g
gi
oi
o E
B
mNB
NE +=
+= g
gi
oi
o E
B
mB
ENF
72. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of OOIP by MBECalculation of OOIP by MBEyy
oi
E
mB
E +
FP
m = 0.6m = 0.5m = 0.4
g
gi
oi
o E
B
E +
0 1060 0930 08110 6713800
0.0570.0510.0435.8073900
0000x1064000
0 2400 2110 18324 0943600
0.1670.1470.12717.3023700
0.1060.0930.08110.6713800
0.4050.3580.31141.1303400
0.3180.2440.24331.8983500
0.2400.2110.18324.0943600
73. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of OOIP by MBECalculation of OOIP by MBEyy
F
From Fig.
m = 0 5m = 0.5
N = 115 x 106 STB
oi
E
mB
E + g
gi
oi
o E
B
E +
74. Applied Reservoir Engineering : Dr. Hamid Khattab
3. Water drive reservoirs3. Water drive reservoirs
Edge water Bottom water
Finite Infinite Finite Infinite
Oil Oil
Water
W W
Water
75. Applied Reservoir Engineering : Dr. Hamid Khattab
3. Water drive reservoirs3. Water drive reservoirs
Characteristics
-P decline very gradually
-Wp high for lower structure wells
-Low GOR
-R.F > R.Fgac cap > R.Fdepletion
77. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of OOIP by MBECalculation of OOIP by MBEyy
Rearrange MBE as an equation of a straight line:
( )[ ] ( )[ ] egssioiowpgspop WBrrBBNBwBrRBN +−+−=+−+∴
eo WENF +=
o
e
o E
W
N
E
F
+=∴
oo
78. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of OOIP by MBECalculation of OOIP by MBEyy
Example 15 :
Calculate (N) for the following bpttom water drive reservoir of
known (We) value:
P Np Bo Rs Rp Bg We
4000 0x106 1.40 700 700 0.0010 0x106
3900 3.385 1.38 680 780 0.0013 3.912
3800 10.660 1.36 660 890 0.0016 13.635
3700 19.580 1.34 630 1050 0.0019 23.265
3600 27.518 1.32 600 1190 0.0022 44.044
79. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of OOIP by MBECalculation of OOIP by MBEyy
Solution :
o
e
o E
W
N
E
F +=
P F Eo F/Eo We/Eo
4000 ―x106 ― ―x106 ―x106
3900 5.111 0.006 851.89 652
3800 18.420 0.024 767.52 568
3700 41.862 0.073 573.45 373.53700 41.862 0.073 573.45 373.5
3600 72.042 0.140 514.38 314.6
oE
F
o
o
45From Fig.
6
10200 ×=N
oe EW
N = 200 x 106
80. Applied Reservoir Engineering : Dr. Hamid Khattab
4. Combination drive reservoir4. Combination drive reservoir
Characteristics:
I W f l t t ll-Increase Wp from low structure wells
-Increase GOR from high structure wells
-Relativity rapid decline of Py p f
-R.F > R.Fwater influx
81. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of OOIP by MBECalculation of OOIP by MBEyy
free gas
iGB giGB
(N-Np)Bo
oi
gi
NB
GB
m =
oiNB
gi
Pi
( ) ( ) gasfreeBwWBNNGBNB wpeopgioi +−+−=+
( ) RNNNNGf
P<Pi
Pi
( ) ppspsi RNrNNNrGgasfree −−−+=
( ) ( )
( )[ ]
wpeopoioi BwWBNNmNBNB −+−=+∴
( )[ ] ( )BwWBrRBN −−−+
( )[ ] gppspsi BRNrNNNr −−−+
( )[ ] ( )
( ) ( )gig
gi
oi
gssioio
wpegspop
BB
B
mB
BrrBB
BwWBrRBN
N
−+−+−
+
=∴
82. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of OOIP by MBECalculation of OOIP by MBEyy
This equation includes 3 unknown (We, m & N)
Rearange this equation as a straight line equation
( )[ ] ( )[ ] ( ) egig
oi
gssioiowpgspop WBB
B
mB
NBrrBBNBwBrRBN +
−+−+−=+−+∴
g q g q
( )[ ] [ ] ( )gg
gi
gpgpp
B
eg
oi
o WE
B
mB
ENF +
+= g
giB
e
mB
W
N
mB
F
+=∴
g
gi
oi
o E
B
mB
E
F
+
o
45
g
gi
oi
og
gi
oi
o E
B
mB
EE
B
mB
E ++
45
N
If We is assumed to be known and m is calculated
by geological dat. N can be obtained
g
gi
oi
o
e
E
B
mB
E
W
+
N
83. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of OOIP by MBECalculation of OOIP by MBE
Example 16 :
yy
Calculate the original oil in place (N)for the following combination drive
reservoir assuming that m=0.5 and values of (We) are given:
P Np Bo rs Rp Bg We
4000 0x106 1 351 600 600 0 00100 0x1064000 0x106 1.351 600 600 0.00100 0x106
3800 4.942 1.336 567 1140 0.00105 0.515
3600 8.869 1.322 540 1150 0.00109 1.097
3400 17.154 1.301 491 1325 0.00120 3.011
84. Applied Reservoir Engineering : Dr. Hamid Khattab
Calculation of OOIP by MBECalculation of OOIP by MBE
Solution :
yy
――――0x1064000
EoFP g
gi
oi
o E
B
mB
E
F
+ g
gi
oi
o
e
E
B
mB
E
W
+g
gi
oi
o E
B
mB
E +
13 95183 950 21590 080839 7153400
11.29181.290.09720.036417.6223600
9.66x106179.66x1060.05330.01969.5763800
0x104000
13.95183.950.21590.080839.7153400
g
i
oi
o E
B
mB
E
F
+
F F giB
o
45From Fig.
STBN 6
10170×=
g
gi
oi
o
e
E
B
mB
E
W
+
6
10170 ×=N
85. Applied Reservoir Engineering : Dr. Hamid Khattab
Uses of MBE
Calculation of (N), (G) and (We)
Prediction of future performance
Difficulties of its applicationDifficulties of its application
Lackof PVT data
Assume constant gas composition
Production data (NP, GP and WP)
Pi and We calculations
Limitation of MBE application
Thick formation
High permeabilityHigh permeability
Homogeneous formation
Low oil viscosity
N ti t d iNo active water drive
No large gas cap
86. Applied Reservoir Engineering : Dr. Hamid Khattab
S l ti f PVT d t f MBE ppli ti sSelection of PVT data for MBE applications
Depletion drive flash
Gas cap drive differential
C bi ti (fl h diff )
rsCombination (flash + diff.)
Water drive flash
Low volatile oil differential
rs
High volatile oil flash
Moderate volatile (flash + diff.)
pp
difflash ff
87. Applied Reservoir Engineering : Dr. Hamid Khattab
Water in flux
Due to: Cw, Cf and artesian flow
We
Oil
Bottom water Edge water Linear flux
Oil
Oil
water
WW
water
88. Applied Reservoir Engineering : Dr. Hamid Khattab
Flow regimes
Steady state semi-steady state Unsteady state
Outer boundary condition
Infinite LimitedInfinite Limited
89. Applied Reservoir Engineering : Dr. Hamid Khattab
Steady state water influx
- Open external boundary
- ∆P/∆r = C with time
- qe=qw=C with time
- Strong We
- Steady state equation (Darcy law)y q ( y )
pe
qw qe
pw
rrw
rer
90. Applied Reservoir Engineering : Dr. Hamid Khattab
Hydraulic analogHydraulic analog
( )∝
∆∝
PPdtdW
Pq Pi
( )
( )
( )∑ ∆
−=
−∝
PPkW
PPkdtdW
PPdtdW
ie
ie
Pw
( )∑ ∆−= tPPkW ie
x
screen sand
q
constantinfluxwater:k
( ) curve(Pust)underarea:∑ ∆− tPPi
C l l f KCalculation of K:
Water influx rate = oil rate + gas rate + water prod. rate
dWdNdNdW
)()( PPkB
dt
dW
BrR
dt
dN
B
dt
dN
dt
dW
iw
P
gsp
P
o
Pe
−=+−+=
91. Applied Reservoir Engineering : Dr. Hamid Khattab
Example :
C l l t K i th f ll i d t P 3500 i P 3340Calculate K using the following data: Pi=3500 psi, P=3340
(Bo=0.00082 bbl/SCF), Qw=0, Bw=1.1 bbl/STB and Qo=13300 STB/day
Solution :
psidaybblk
daybbldtdWe
//130
)33403500(
20800
/20800000082.0)700900(133004.113300
==∴
=+×−×+×=
)33403500( −
Pi
t1 t2 t3 t4∆t1 ∆t2 ∆t3 ∆t4
A1 A2 A3 A4
Calculation of ( )∑ ∆− tPPi
P1
A1 A2 A3 A4
( )
( )
1
1
4321
2
t
PP
AAAAtPP
i
i
∆
−
=
+++=∆−∑
P2
P3
( ) ( )
( ) ( )32
2
21
2
t
PPPP
t
PPPP
ii
ii
∆
−+−
+
∆
−+−
+
P3
P4
( ) ( )
4
43
3
2
2
t
PPPP
t
ii
∆
−+−
+
∆+
92. Applied Reservoir Engineering : Dr. Hamid Khattab
Example :
The pressure history of a steady-state water drive reservoir is
given as follows:
Tdays : 0 100 200 300 400
Ppsi : 3500 3450 3410 3380 3340
If k=130 bbl/day/psi,
calculate We at 100, 200,300 & 400 dayse , , y
94. Applied Reservoir Engineering : Dr. Hamid Khattab
SemiSemi--steadysteady--state water influxstate water influxSemiSemi steadysteady state water influxstate water influx
As the water drains from the aquifer, the aquifer radius (re)
increases with time, there for (re/rw) is replaced by a timeincreases with time, there for (re/rw) is replaced by a time
dependent function (re/rw)→at
PPCPPCPPkhdW × −
)()()(10087 3
PPCdW
atn
PPC
rrn
PPC
rrn
PPkh
dt
dW i
we
we
we
wee −
→
−
=
−×
=∴
)(
)(
)(
)(
)(
)(
)(1008.7
lllµ
PP
atn
PPC
dt
dW ie −
=∴
)(
)(
)(
l
t
atn
PP
CW i
e ∆
−
=∴ ∑ )(
)(
l
95. Applied Reservoir Engineering : Dr. Hamid Khattab
The two unknown constants (a and C) are determined as:
(at)ln
CdtdW
PP
e
i 1
)(
)(
=
−
)(
)(
dtdW
PP
e
i −
tan lnl
CCdtdW
PP
e
i 11
)(
)(
+=
−
∴
)( We
1
C
1
Plott this equation as a straight line:
tln
anl
C
1
Gives slop = and intercept =
C
1
CC
97. Applied Reservoir Engineering : Dr. Hamid Khattab
tmonth tdays ∆We/ ∆t (Pi-P) Ln t (Pi-P)/ dWe/ dt
0 0 0 0 ― ―
6 182.5 389 19 5.207 0.049
12 365 1279 84 5.900 0.06612 365 1279 84 5.900 0.066
18 547.5 2158 150 6.305 0.070
24 780 3187 246 6.593 0.077
30 912 5 3844 308 6 816 0 08130 912.5 3844 308 6.816 0.081
)(
)(
dtdW
PPi −002.0
1
=
C
From Fig.
)( dtdWe
∴C = 50
Using any point in the straight line
C
002.0
1
=
C
Using any point in the straight line
a = 0.064
∑
− PP
W i
50
tln
∑=∴
ln(0.064t)
W i
e 50
98. Applied Reservoir Engineering : Dr. Hamid Khattab
Example 18:Example 18:
Using data of example (18) calculate the cumulative water influx (We)
after 39 months (1186.25 days) where the pressure equals 3379 psi
Solution :
PPPP
dt
ta
PP
ta
PP
WW ii
ee
−
+
−
×+= 250
2
39
1
36
3639
lnln
[ ]34163793337937933 −−
[ ]109525.11862
)1095064.0(
34163793
)25.1186064.0(
33793793
50102388 3
××
×
+
×
×+×=
lnln
33 33
10508.420102388 ×+×=
bbls3
102809×=
99. Applied Reservoir Engineering : Dr. Hamid Khattab
UnsteadyUnsteady--state water influxstate water influxUnsteadyUnsteady state water influxstate water influx
- P and q = C with time
- q = 0 at re, q=qmax at rw
Closed extended boundry
rw
- Closed extended boundry
- We due to Cw and Cf
100. Applied Reservoir Engineering : Dr. Hamid Khattab
Hydraulic analogHydraulic analogHydraulic analogHydraulic analog
Pi
P2
P1
Pw
qx q
screen
sand sand sand