This document provides an overview of improved oil recovery (IOR) and enhanced oil recovery (EOR) methods. It discusses rock and fluid properties important for reservoir evaluation including porosity, permeability, saturation, bubble point pressure, formation volume factor, oil gravity, and gas-oil ratio. Tables with core analysis data from various wells showing these properties are also presented.
Enhanced Oil Recovery
It’s a process for recovering mostly every Barrels of Oil to get out all of remaining oil in it.
And this is done by EOR technologies
Enhanced Oil Recovery
Mainly the following process are done for Enhanced oil recovery
Water injection
Gas injection
Reducing residual oil saturation, SOR (alcohol, polymers, surfactants injection)
Thermal: steam injection (to heating of the reservoir to lower the viscosity)
There are three primary techniques of EOR: gas injection, thermal injection, and chemical injection. Gas injection, which uses gases such as natural gas, nitrogen, or carbon dioxide (CO2), accounts for nearly 60 percent of EOR production in the United States. Thermal injection, which involves the introduction of heat, accounts for 40 percent of EOR production in the United States, with most of it occurring in California. Chemical injection, which can involve the use of long-chained molecules called polymers to increase the effectiveness of waterfloods, accounts for about one percent of EOR production in the United States. In 2013, a technique called Plasma-Pulse technology was introduced into the United States from Russia. This technique can result in another 50 percent of improvement in existing well production.
Enhanced Oil Recovery
It’s a process for recovering mostly every Barrels of Oil to get out all of remaining oil in it.
And this is done by EOR technologies
Enhanced Oil Recovery
Mainly the following process are done for Enhanced oil recovery
Water injection
Gas injection
Reducing residual oil saturation, SOR (alcohol, polymers, surfactants injection)
Thermal: steam injection (to heating of the reservoir to lower the viscosity)
There are three primary techniques of EOR: gas injection, thermal injection, and chemical injection. Gas injection, which uses gases such as natural gas, nitrogen, or carbon dioxide (CO2), accounts for nearly 60 percent of EOR production in the United States. Thermal injection, which involves the introduction of heat, accounts for 40 percent of EOR production in the United States, with most of it occurring in California. Chemical injection, which can involve the use of long-chained molecules called polymers to increase the effectiveness of waterfloods, accounts for about one percent of EOR production in the United States. In 2013, a technique called Plasma-Pulse technology was introduced into the United States from Russia. This technique can result in another 50 percent of improvement in existing well production.
Low Salinity Water Injection by Shrinath GhadgeShrinath Ghadge
Low salinity water flooding has been recognized as prominent enhanced oil recovery technique, acting at microscopic scale by reducing residual oil saturation thanks to a combination of intertwined mechanisms.
In the last ten years, several studies and applications have been performed by Academia and Oil Companies giving indication of the process potentialities to increase oil production both in clastic and carbonate reservoirs.
This presentation tackles one of the problem in oil industry, which is sand that is produced in the oil wells. Brief description about the problem, its causes, effects and solutions are proposed.
Low Salinity Water Injection by Shrinath GhadgeShrinath Ghadge
Low salinity water flooding has been recognized as prominent enhanced oil recovery technique, acting at microscopic scale by reducing residual oil saturation thanks to a combination of intertwined mechanisms.
In the last ten years, several studies and applications have been performed by Academia and Oil Companies giving indication of the process potentialities to increase oil production both in clastic and carbonate reservoirs.
This presentation tackles one of the problem in oil industry, which is sand that is produced in the oil wells. Brief description about the problem, its causes, effects and solutions are proposed.
Field Development Project : Gelama MerahHami Asma'i
A green field development project located in Sabah Basin comprises the whole upstream field development cycle from geology, reservoir studies to production facilities and economics. The objective is to come out with the best strategy to develop the field starting from our very own effort of reservoir characterization out of log and core data. Under supervision of lecturers, this project was completed as per scheduled.
Among new technical methodologies applied upon the completion this project:
1. Cubic Spline Interpolation Method in bulk volume calculation
2. Monte Carlo probabilistic method in reserve estimation
3. Reservoir Opportunity Index (ROI) method in well placement
Project was assessed by PETRONAS custodians.
DrilSmooth system is a unique, water-based drilling fluid .pptxWaelElEssawy2
DrilSmooth system is a unique, water-based drilling fluid developed for fractured and stabilizing mechanically weak or poorly consolidated formations and drilling high-angle or horizontal wells.
bubble-particle collision and attachment and detachment sub processes, implies that certain bubble size distributions have different effects over the flotation rates of coarse and fine particles
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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.
Online aptitude test management system project report.pdfKamal Acharya
The purpose of on-line aptitude test system is to take online test in an efficient manner and no time wasting for checking the paper. The main objective of on-line aptitude test system is to efficiently evaluate the candidate thoroughly through a fully automated system that not only saves lot of time but also gives fast results. For students they give papers according to their convenience and time and there is no need of using extra thing like paper, pen etc. This can be used in educational institutions as well as in corporate world. Can be used anywhere any time as it is a web based application (user Location doesn’t matter). No restriction that examiner has to be present when the candidate takes the test.
Every time when lecturers/professors need to conduct examinations they have to sit down think about the questions and then create a whole new set of questions for each and every exam. In some cases the professor may want to give an open book online exam that is the student can take the exam any time anywhere, but the student might have to answer the questions in a limited time period. The professor may want to change the sequence of questions for every student. The problem that a student has is whenever a date for the exam is declared the student has to take it and there is no way he can take it at some other time. This project will create an interface for the examiner to create and store questions in a repository. It will also create an interface for the student to take examinations at his convenience and the questions and/or exams may be timed. Thereby creating an application which can be used by examiners and examinee’s simultaneously.
Examination System is very useful for Teachers/Professors. As in the teaching profession, you are responsible for writing question papers. In the conventional method, you write the question paper on paper, keep question papers separate from answers and all this information you have to keep in a locker to avoid unauthorized access. Using the Examination System you can create a question paper and everything will be written to a single exam file in encrypted format. You can set the General and Administrator password to avoid unauthorized access to your question paper. Every time you start the examination, the program shuffles all the questions and selects them randomly from the database, which reduces the chances of memorizing the questions.
Literature Review Basics and Understanding Reference Management.pptxDr Ramhari Poudyal
Three-day training on academic research focuses on analytical tools at United Technical College, supported by the University Grant Commission, Nepal. 24-26 May 2024
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.
5. 5
Reservoir:
A substance body of rock having sufficient porosity and permeability to store and
transmit fluids; (eg; Sandstone, Carbonate, Fracture Basement … etc...)
23. Oil Gas Water
• Estimating
properties of
reservoir
water is
important
for reservoir
calculations,
specifically
for those
with water
influx
Reservoir fluids
23
24. Bubble Point Pressure
The bubble point pressure is defined as the
pressure at which the first bubble of gas comes
out of solution.
At this point, we can say the oil is saturated - it
cannot hold anymore gas. Above this pressure the
oil is under saturated, and the oil acts as a single-
phase liquid.
At and below this pressure the oil is saturated,
and any lowering of the pressure causes gas to be
liberated resulting in two-phase flow.
24
25. Oil Gravity
Oil gravity relates the density of oil to that of the density of water.
API gravity is gradated in degrees on a hydrometer instrument and was
designed so that most values would fall between 10° and 70° API.
It ranges from 45 °API (light oil) through 20 °API (medium density) to 10
°API (heavy oil). The conversion from API gravity (oil field units) to relative
gravity (relative to water) is:
25
26. Formation Volume Factor
The ratio of the volume of oil and dissolved gas at reservoir (in-situ) conditions to
the volume of oil at stock tank (surface) conditions, volume factors are needed to
convert measured surface volumes to reservoir conditions. It is defined as:
As pressure increases, the amount of solution gas that the oil can dissolve
increases such that the oil swells, and so the formation volume factor exceeds 1.0
oil formation volume factor is dominated by swelling below the bubble point
pressure (due to dissolved gas), and by compressibility above the bubble point
pressure (since all available gas is now dissolved).
Solution gas
Compressibility of oil
26
27. Gas Oil Ratio
The solution gas-oil ratio is the amount of gas
dissolved in the oil at any pressure.
GOR increases approximately linearly with
pressure and is a function of the oil and gas
composition. A heavy oil contains less dissolved
gas than a light oil.
The solution gas-oil ratio increases with
pressure until the bubble point pressure is
reached, after which it is a constant, and the oil
is said to be under saturated.
27
29. y = 26
y = -0.0935x + 143.14
R² = 0.9457
0.0
10.0
20.0
30.0
1150 1200 1250 1300 1350 1400
API
Depth (m)
API Vs Depth of Fal-1&Fal-5
y = -0.1241x + 184.59
R² = 0.946
0.0
10.0
20.0
30.0
1280 1320 1360 1400
API
Depth (m)
API Vs Depth of Fal-3&Fenti
y = -0.036x + 85.636
R² = 0.5786
20.0
30.0
40.0
50.0
1150 1200 1250 1300 1350 1400
PourPoint(℃)
Depth (m)
Pour Point Vs Depth of Fal-1& Fal-5
As the depth is increasing, oil viscosity decreases, API decreases, and pour point decreases
Low bubble pressure: 300~650psi
Low GOR: 42.8~89.6scf/bbl
Medium to heavy oil: oil viscosity 30.4 ~ 360cp;
API 14.5~23.8
Medium to high pour point: 15.0~42.2℃
1
2
3
29
33. A core is a sample of rock in the shape of a cylinder. Taken from the side of a
drilled oil or gas well, a core is then dissected into multiple core plugs, or
small cylindrical samples measuring about 1 inch in diameter and 3 inches
long.
Core Definition
Types of Cores:
There are several types of cores that can be recovered from the well:
Full-diameter cores.
Oriented cores.
Native state cores and
Sidewall cores.
33
36. Special Core Analysis:
Detailed understanding of a reservoir requires additional measurements obtained in the special
core analysis laboratory (SCAL). Examples include
ƒ
Calibrating electrical logging measurements of porosity and saturation.
ƒ
Determining a formation-specific cutoff value for the relaxation time from a nuclear
magnetic resonance (NMR) log.
ƒ
Determining capillary pressure measurements to indicate distributions of pore throats and
evaluating saturation distribution as a function of height in a formation.
ƒ
Relative permeability determines the multiphase flow character of the formation.
Evaluating wettability.
36
49. Routine Core Analysis:
Measurement of basic properties helps you
determine if a rock contains a fluid-filled space
(porosity) and hydrocarbons in that space
(saturation), and the ability of those hydrocarbon
fluids to be produced (permeability). Core gamma
logging links core depth to logging depth.
Computed tomography (CT) scans indicate core
heterogeneity.
49
90. 90
The STOIIP of P1, P2, P3 (Proved, Probable, Possible) in each reservoir
is assessed using the volumetric calculation method. The formula is
shown as below.
STOIIP = Ao * H * Por. * So / Boi * 6.29
Where: STOIIP= Original Oil in Place, MMstb
Ao= Oil bearing area (km2)
H = Net pay (m)
Por= Porosity (fraction)
So =Oil saturation (fraction)
Boi= Oil formation factor (v/v)
Volumetric Assessment:
Example of Mirmir area – Melut Basin - DPOC
91. 91
PROVED/PROBABLE/POSSIBLE CATEGORIES
(HALF-WAY CONCEPT)
The categories and halfway concept may be overridden by some other geological,
geophysical and engineering data of which the basis and assumptions must be clearly stated.
Range of Uncertainty Categories for Hydrocarbon Accumulation
92. 92
Based on structure map of pay zones, the boundary line of oil or gas bearing area is
determined by fault boundary, lithology boundary and fluid contacts. Fluid contacts
often are determined by well testing, well logging evaluation and MDT data.
Oil Bearing Area
Net pay for each layer in wells is obtained from well log interpretation. Based on
the net pay contour map, net pay of the hydrocarbon reservoir is determined by
weighting of hydrocarbon bearing area.
Net Pay
Porosity of net pay in wells is obtained from well log interpretation. For a
hydrocarbon reservoir, porosity value is determined by weighting of net pay.
Porosity
Oil saturation of net pay in wells is obtained from well log interpretation. For a
hydrocarbon reservoir, oil saturation value is determined by weighting of net pay.
Oil Saturation
Volume factor is determined based on the PVT data, and obtained from reservoir
engineering analysis.
Formation Volume Factor (Boi)
103. This is the recovery of hydrocarbons from the reservoir using
the natural energy of the reservoir as a drive.
Primary Recovery
(i) Solution gas drive
(ii) Gas cap drive
(iii) Water drive
(iv) Gravity drainage
(v) Combination or mixed drive
103
104. This is recovery aided or driven by the injection of water or
gas from the surface.
Secondary Recovery (IOR)
(i) Waterflooding
(ii) Gasflooding
104
119. Water flooding Reduces Oil Viscosity Well sorting
Large grain Low API
SCAL Formation pressure
Saturation
Single liquid phase
Cubic packing High APIMiscible
1 2 3
4 5 6
7 8 9
10 11 12
119
A
120. Light oil N2
High permeabilityAbove the bubble pointpsi
T2 cut-off48% Porosity
Steam injectionOil gas, or water Oil
Good porosity
Heavy Oil
Secondary recovery
A 120
123. Briefly discus the following:
A. Reservoir pressure
B. Injection well
C. Viscosity
D. Pour point
E. Secondary porosity
F. Wettability
G. Capillary pressure
H. Absolute Open Flow Potential (AOF/AOFP)
I. Computed Tomography (CT)
Exercise 1
123
126. 126
Exercise 4
The STOIIP of P1, P2, P3 (Proved, Probable, Possible) in each reservoir
is assessed using the volumetric calculation method. The formula is
shown as below.
Calculate STOIIP for L_Aradeiba-4-1 Foramation?
STOIIP = Ao * H * Por. * So / Boi * 6.29
Where: STOIIP= Original Oil in Place, MMstb
Ao= Oil bearing area (km2)
H = Net pay (m)
Por= Porosity (fraction)
So =Oil saturation (fraction)
Boi= Oil formation factor (FVF)
129. 129
(A) (B) (C)
EOR Type EOR methods Main Mechanism
1 Thermal Miscible Improve swept efficiency
2 Chemical Hot Water Make oil volumetric swell
3 Gas Injection Gas Injection Viscosity reduction
Exercise 5
Match the following column A, B & C.