petroleum production engineering i lecture 2: production
TRANSCRIPT
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Tishk International UniversityEngineering FacultyPetroleum and Mining Department
Petroleum Production Engineering I
4-Grade- Fall Semester 2021-2022
Lecture 2: Production Systems
Instructor: Frzan AliFrzan Ali Petroleum Production
Engineering I
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• Production Engineering:
Part of petroleum engineering which attempts to maximize production in a cost-effective manner.
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Introduction
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A sketch of a petroleum production system Frzan Ali 3
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A typical hydrocarbon phase diagram
0 50 150 200 250 300 350100
1000
500
1500
2000
2500
3000
3500
4000
Reservoir Temperature (oF)
Rese
rvoir P
ress
ure
(psi
a)
Liquid Volum
e40%
20%
10%
80%
5% 0%
Bubble Point
Gas ReservoirsRetrograde
Condensate
Reservoirs
Critical
Point
pi, T
ptf, Ttf
pwf, Twf
Dew Point
Cri
condenth
erm
Poin
tFrzan Ali 4
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Gas Oil Ratio - GOR
•Wells in the same reservoir can fall into categories of oil, condensate, and gas wells depending on the producing GOR (gas oil ratio)
•SCF: Standard Cubic Feet. STB: Stock Tank Barrel
• Gas well: GOR>100K scf/stb• Gas condensate: 5K<GOR<100K scf/stb• Oil well: GOR<5K
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Drive Mechanisms
Oil reservoirs can be classified based on boundary type
which determines driving mechanism:
(1) Water-drive reservoir
(2) Gas-cap drive reservoir
(3) Dissolved-gas drive reservoir.
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Oil
Water
WOC
A sketch of a water drive reservoir
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Edge-water drive advantage:
• Reservoir pressure can remain in its initial value above bubble-point
pressure
• steady-state flow can be remained for a long time before water break
through
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Gas Cap
Oil
A sketch of a gas-cap drive
reservoir
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A sketch of a dissolved-gas drive reservoir
Oil and Gas
Reservoir
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A sketch of a typical flowing oil well
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A sketch of a wellhead
Choke
Wing Valve
Master Valve
Tubing Pressure Gauge
Flow Fitting
Tubing
Intermediate Casing
Surface CasingLowermost Casing Head
Uppermost Casing Head
Casing Valve
Casing Pressure Gauge
Production Casing
Tubing head
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A sketch of a casing head
Bowl
Production
Casing
Casing
Head
Surface
Casing
Casing Hanger
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A sketch of a tubing head
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A sketch of a Christmas tree
Choke Wing Valve Wing Valve Choke
Master Valve
Tubing Head Adapter
Swabbing Valve
Top connection
Gauge Valve
Flow Fitting
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Sketch of a surface valve
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A sketch of a wellhead choke
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The procedures to open a well:
(1) The master valve is barely open (cracked). Escaping fluid makes a hissing sound. When the fluid no longer hisses through the valve, the pressure has been equalized. Then the master valve is opened wide.
(2) If there are no oil leaks the operator cracks the next downstream valve that is closed. Usually this will be either the second (backup) master valve or a wing valve. Again, when the hissing sound stops the valve is opened wide.
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(3) Open other downstream valves the same way.
(4) To read the tubing pressure gauge, the operator must open the needle valve at the top of the Christmas tree. After reading and recording the pressure, the operator may close the valve again to protect the gauge.
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The procedures to open a well:
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Conventional horizontal separator
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Double action piston pump
Suction Suction
Discharge Discharge
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Elements of a typical reciprocating compressor Frzan Ali 22
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The major objective of the safety system is toprevent the release of hydrocarbons from theprocess and to minimize the adverse effects ofsuch releases if they occur. This can be achievedby
(1) preventing undesirable events(2) shutting-in the process(3) recovering released fluids(4) preventing ignition
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Safety System
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The modes of safety system operation
Include:
a. Automatic monitoring by sensors
b. Automatic protective action
c. Emergency shut-down
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Protection concepts and safety analysis are based
on undesirable events which include
A. Overpressure caused by1. increased input flow due to upstream flow control device
failure
2. decreased output flow due to blockage
3. heating of closed system
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B. Leak caused by1. corrosion2. erosion3. mechanical failure due to temperature change, over- and under-pressure, and
external impact force
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C. Liquid overflow caused by1. increased input flow due to upstream flow control device
failure
2. decreased output flow due to blockage in the liquid discharge
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Protection concepts and safety analysis are based
on undesirable events which include
D. Gas blowby caused by1. increased input flow due to upstream flow control device failure2. decreased output flow due to blockage in the gas discharge
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E. Under-pressure caused by1. outlet flow control device (e.g., choke) failure
2. inlet blockage
3. cooling of closed system
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Protection concepts and safety analysis are based
on undesirable events which include
F. Excess temperature caused by
1. over-fueling of burner
2. external fire
3. spark emission
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Process and Instrumentation Diagrams (P&ID)
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Engineering I28
P&ID is a detailed diagram in the process industry which shows the piping
and process equipment together with the instrumentation and control devices.
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Flow Safety
Valve
FSV
Burner Safety
Low
BSL
Pressure Safety
High & Low
PSHL
Pressure Safety
Element
PSE
Flow Safety
High
FSH
Flow Safety
Low
FSL
Pressure Safety Valve
PSVPSV
Level Safety
Low
LSLLSH
Level Safety
High
Temperature
Safety High
TSH TSL
Temperature
Safety Low
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P&ID Symbols
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Level Safety
High & Low
LSHL
Flow Safety
High & Low
FSHL
Temperature
Safety
High & Low
TSHL
Temperature
Safety Element
TSE
Pressure
Safety High
PSH
Pressure
Safety Low
PSL
Surface Safety Valve
SSV SSV
Underwater Safety Valve
USV USV
Blow Down Valve
BDV BDV
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P&ID Symbols
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MAWP > SITP
<10’
(3M)
TSE
SSV
PSHL FSV
Outlet
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P&ID Symbols
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Safety system designs for underwater wellhead flow lines
MAWP > SITP
USV
Outlet
PSHL FSV
MAWP > SITP
USV
Outlet
FSVPSHL
Denotes platform limits
PSL SDV
Option 1
Option 2
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P&ID Symbols
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Safety system design for pressure vessel
PSHL
PSV
Gas outlet
FSV
Gas makeup systemTSE
Inlet
LSL
LSH
FSV
Oil outlet
Pressure
Vessel
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P&ID Symbols
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Safety system design for pipeline pumps
PSV
TSE
PSHL
FSV
SDV
Discharge
PumpFrom storage
component
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P&ID Symbols