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pdf 2 Flashcards

1
Q

are installed
after drilling is complete.

A

Oil and gas wells

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2
Q

typically produce a mixture of hydrocarbon gases, liquids and 2
water.

A

Oil and gas wells

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3
Q

the structure at the surface of a well that comprises of valves, spools and adapters

A

wellhead

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4
Q

to control the pressure from the well
to ensure safe operation and to manage the flow from the well

A

wellhead

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5
Q

can also provide a means of gas injection or attaching a
pump to increase production.

A

wellhead

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6
Q

Pressures in the well can exceed….

A

20,000 kPag

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7
Q

takes the gas- liquid mixture from the wellheads and divides it into three
components - water, condensate, and gas.

A

separator

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8
Q

takes flow from one well, and separates the phases into produced gas, produced
condensate, and produced water for well monitoring and production accounting

A

The test separator header

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9
Q

takes flow from all the wells and separates the phases into produced
gas, produced condensate, and produced water, which is metered for accounting purposes
before being recombined and sent to a gas processing facility.

A

the group separator

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10
Q

a mechanical piece of equipment that is used to increase
the pressure and reduce the volume of a gas stream

A

compressor

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11
Q

It is critical in natural
gas processing, transportation, and delivery of natural gas to our homes.

A

compressor

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12
Q

maintains suction
pressure and allows
the compressor to
operate even when
there is no supply of
gas coming into the
compressor

A

the recycle line

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13
Q

are
not compressible and can cause
catastrophic damage in the
compressor

A

liquids

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14
Q

require
a suction scrubber to remove any
liquids in the stream prior to
compressing the gas.

A

most types of compressors

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15
Q

can be a concern in compressors due to changing pressures from compressing and recycling gas, as well as the wide
temperature operating range due to heating from compression and then after-cooling.

A

hydrates

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16
Q

Common
products stored in tank farms are:

A

-diesel
-gasoline
-NGLs
-crude
-waste water
-etc

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17
Q

also called oil terminals

A

tank farms

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18
Q

form in solutions that contain water and gas, like emulsion. Under high pressures and low temperatures, the
water/gas structure will form a crystalline solid that can block flow in pipe

A

hydrates

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19
Q

The outlet of most
compressors is around

A

140-160C

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20
Q

the temperature can
increase significantly

every when..?

A

during compression

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21
Q

can flow to one of two headers,
the group separator header or
the test separator.

A

Emulsion from the well

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22
Q

tank farms Products supplied from upstream or midstream
facilities are transported via

A

-pipeline
-truck
-train
-boat

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23
Q

are storage facilities for
hydrocarbon liquids

A

tank farms

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24
Q

The storage capacity of
a tank farm manages_______ in supply upstream

A

fluctuations

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25
Q

The storage capacity of
a tank farm manages __(1)___ in supply upstream and ________ _______ to prevent costly delays in distribution

A

demand downstream

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26
Q

There are two main categories of tank roofs

A

: fixed and floating

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27
Q

are solidly connected to the top of the tank wall and are either
welded or bolted to remain stationary during the operation of the tank.

A

fixed roofs

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28
Q

They can be flat cylinders, cones, or domed shaped.

A

fixed roofs

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29
Q

roofs that
can be internal or external.

A

floating roofs

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30
Q

similarity of floating and fixed roofs

A

Both have a roof that floats
on the liquid level in the tank
that can move up or down
as the product level rises and
falls

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31
Q

has an additional fixed roof at the top of the tank

A

internal floating roof

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32
Q

only uses the floating roof
to separate tank contents from the environment

A

external floating roof tank

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33
Q

Tanks can have many other components like:

A

coatings, insulation, mixers, etc.

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34
Q

Transportation of hydrocarbons can be performed by

A

pipeline, trucking, or rail.

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35
Q

The product is brought into the terminal
by tank cars. The tank cars
contain ..?

A

hydrocarbon liquids and
flammable vapours

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36
Q

can be attached to the tankcars
to remove the
product. In many
cases, product can be
removed from multiple
tank cars at once.

A

Hoses with special
couplings

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37
Q

is used to
pump liquid product
from the bottom of the
tank car to the storage
tank at the facility.

A

pump

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38
Q

can be used to transport liquid hydrocarbons and pressurized gases

A

Rail cars

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39
Q

The design of the tank car, including the pressure rating and
material, dictates which type of product it can carry. Common commodities include

A

crude oil, ethanol, diesel, etc.

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40
Q

is also a good alternative when
there is no pipeline infrastructure in place.

A

Rail transportation

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41
Q

generally considered a safer alternative, with a
lower likelihood of a spill.

A

pipelines

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42
Q

One of the biggest concerns
for rail transportation is

A

derailment

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43
Q

enters the bottom
of the tower, contacting
amine as it rises up

A

sour gas

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44
Q

weak
points of tank cars

A

Topfittings, heat shields, and
valves

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45
Q

stripped of
H2S and CO2 exits the top of
the contactor

A

Sweetened gas

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46
Q

enters
the top of the
contactor tower and
flows downward
through the trays of
the tower

A

Lean amine

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47
Q

absorbs H2S
and CO2 from the
gas.

A

amine

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48
Q

exits the bottom
of the tower and flows to the
flash drum which operates at
a much lower pressure,
flashing off some of the
absorbed gases.

A

Rich amine

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49
Q

enters the
regeneration tower

A

Rich amine

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50
Q

flashes off from the
tower heat and drop in
pressure as it flows down
the tower.

A

H2S
and CO2

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51
Q

is sent to
a condenser to recover water
and amine which is sent
back to the tower.

A

Acid gas off the top of the
regeneration tower

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52
Q

can either be sent to a Claus reaction
process to produce elemental sulphur, or to an
acid gas injection compressor.

A

Acid gas

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53
Q

is sent to a
heater to flash off the
remaining H2S and CO2 in
the amine before it is sent
back to the contactor

A

The amine from the bottom
of the tower

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54
Q

is pumped from
the regenerator tower back
into the contactor tower.

A

Amine is cooled to between
40-60°C

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55
Q

___________produced from wells usually has a high water
content.

A

Natural gas

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56
Q

It is important to remove the water in
order for the gas to meet sales specification requirements..

if not met..

This can cause several issues for natural gas
operations including

A

freezing and hydrate formation, as
well as corrosion.

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57
Q

enters the glycol
contactor and mixes with
glycol.

A

Wet gas

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58
Q

exits the
bottom of the contactor
with water stripped from
the gas stream.

A

glycol

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59
Q

exits
the top of the tower

A

Dry Gas

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60
Q

drops the pressure of the
rich glycol and allows any initial water vapour
and trapped hydrocarbons to separate from the
liquid prior to the stripping tower.

A

The glycol flash drum

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61
Q

recovers heat from the
lean glycol which helps
to preheat the rich
glycol before it enters
the stripping tower.

A

A heat exchanger

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62
Q

enters the stripping
tower and water begins to flash
out of the glycol from the pressure
drop and increased temperature.

A

Rich glycol

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63
Q

exits the
top of the tower with
potential for some
contaminants like
benzene / toluene /
ethyl-benzene / xylene
(BTEX).

A

water vapour

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64
Q

Water vapour exits the
top of the tower with
potential for some
contaminants like

A

-benzene
-toluene
-ethyl-benzene
-xylene

(BTEX).

65
Q

is heated to remove
remaining excess water content
to complete the regeneration.

A

Glycol

66
Q

is an important midstream
process to reduce the vapour pressure of
hydrocarbon liquids to make them safer and
easier to transport.

A

Stabilization

67
Q

enters the
inlet surge drum, off gas
begins to flash off, and water
separates into the water
boot.

A

Condensate from an
upstream process

68
Q

sent downstream for
treatment and / or disposal

A

Water off the bottom of the surge
drum

69
Q

is recovered from the hot
stabilized condensate to preheat the
unstabilized condensate before the
stabilization tower

A

heat

70
Q

Gases flash out of
the condensate
stream due to the

A

heat input into the tower

71
Q

which
causes lighter end
hydrocarbons to
vapourize.

A

Gases flash out
of the condensate stream
due to the
heat input into
the tower

72
Q

maintains a constant
temperature at the bottom of the
tower to ensure any hydrocarbons
with a low boiling point are
vapourized

A

reboiler

73
Q

are sent downstream to a compressor to recover the flashed gases back into the gas process.

A

The gas off the top
of the stabilizer
and surge drum

74
Q

is an important process for
removing more valuable hydrocarbons such as ethane, propane,
butane

A

Natural gas liquids (NGLs) recovery

75
Q

.This process typically operates at high pressure and low
temperatures to cause those hydrocarbons to condense.

A

Natural gas liquids (NGLs) recovery

76
Q

enters the process and flows
through a series of heat exchangers to
drop the temperature.

A

gas

77
Q

is injected into the stream to
prevent any water in the system from
freezing when the temperature goes
below 0°C.

A

glycol

78
Q

is used to drop
the temperature of the gas further,
causing propane and butane and
other NGLs to condense in the gas
stream

A

Refrigerant propane

79
Q

is recovered and
separated from the NGLs in the boot of
the low temperature separator

A

injected

80
Q

is sent downstream to be regenerated.

A

glycol

81
Q

are sent to a
stabilzation tower to remove some
lighter end products and reduce the
vapour pressure

A

Recovered NGLs

82
Q

is sent downstream
typically to a compressor to increase
the pressure and is re-injected to the
stripped gas stream or for further
treating / processing.

A

Stripped gas

83
Q

maintains
temperature at the
bottom of the tower to
boil off any remaining
light end products.

A

reboiler

84
Q

are sent downstream to a
storage bullet which is a
pressurized vessel designed to
store the NGLs at a pressure high
enough to prevent vapourization.

A

NGLs

85
Q

play an important role in the safety of hydrocarbon facilities

A

Flares

86
Q

They provide a
controlled means of releasing product pressure, volume and energy which can be
very hazardous if contained in the wrong situation.

A

Flares

87
Q

The three main components of
a flare system are

A

-flare header piping
-flare knockout drum
- flare stack

88
Q

a network of piping throughout a facility that collects relief
flow paths and directs them to the flare knockout

A

flare header piping

89
Q

is a vessel that captures liquids from a blowdown or relief event.

A

The flare knockout drum or
FKOD

90
Q

is a release of gas and/or liquid product and pressure from the process
piping and equipment.

A

blowdown

91
Q

is a tall cylindrical structure that releases
flammable, toxic or corrosive waste vapours high into the air where they are then
combusted into products that are less harmful to the environment.

A

Flare stack

92
Q

emissions are tightly monitored and regulated.

A

Flare stack

93
Q

keeps a positive
pressure slightly above
atmospheric in the relief
system

A

A continuous purge of
fuel gas

94
Q

controlled with a
pressure regulator valve

A

Pressure

95
Q

Blowdown from other systems
combine in a relief header and are
directed to the

A

flare knockout drum

96
Q

is separated from hydrocarbon
liquids and water

A

gas

97
Q

upstream of the
stack tracks the
emission rate

A

A flow meter

98
Q

typically natural
gas, is controlled
with a pressure
regulating valve.

A

Pilot fuel gas

99
Q

is continuously
burned at the flare stack tip in
order to maintain a constant
source of ignition at the stack.

A

Pilot fuel gas

100
Q

are used to convert heavy oil products into lighter products such as diesel, gasoline, and naphtha.

A

Hydrocracking units

101
Q

This is achieved
by cracking the longer heavier hydrocarbon molecule chains into shorter chains in a reactor, then saturating these shorter chains with hydrogen

A

Hydrocracking units

102
Q

dampens any surges coming
from the inlet and allows for appropriate control of
the feed to the unit.

A

feed surge drum

103
Q

is used to feed the
heavy oil into the unit at the
desired rate.

A

feed pump

104
Q

is critical for the hydrocracking reaction for temperature
control and saturating the hydrocarbons.

A

Hydrogen

105
Q

is critical in the
hydrocracking
unit. Product from the
bottom of the reactor is
cooled and this heat is
used to preheat the feed
oil going to the reactor.

A

Appropriate temperature
control

106
Q

The feedstock to the
reactors consists of the

A

feed oil and hydrogen.

107
Q

This mixture is preheated
in a charge heater to
bring it up to the
required temperature for
the reaction.

A

The feedstock to the
reactors consists of the
feed oil and hydrogen.

108
Q

can come from other units such as a fluidized catalytic cracking unit,
a coker unit, or an atmospheric or vacuum distillation tower including kerosene, gas
oil, light cycle oil, and heavy cycle oil

A

The feed

109
Q

can handle feeds with
more aromatic oils better than catalytic cracking processes.

A

Hydrocracking units

110
Q

is commonly used in
the place of a fluidized catalytic
cracking unit for jet fuel and diesel
production due to the low aromatic
and sulphur and high hydrogen
content of the products.

A

Hydrocracking

111
Q

The
process can yield high quality fuels
and environmentally more friendly fuels
compared to a fluidized catalytic
cracking unit

A

Hydrocracking

112
Q

contain
catalysts which help
convert long heavy
chain molecules into
shorter chain saturated
hydrocarbons. Sulfur
and nitrogen impurities
are also removed.

A

the reactors

113
Q

is used to separate the hydrogen
rich gas, the hydrocarbon
liquids, and water

A

A high pressure separator

114
Q

is recycled back to the reactors
to control the temperature in
the reactors.

A

Cool hydrogen quench gas

115
Q

separates the off gas from the
hydrocarbon liquid in order to get
the desired products.

A

The low pressure separator

116
Q

can be further processed in an amine
unit to remove hydrogen sulfide
and carbon dioxide.

A

Off gas from the hydrocracker

117
Q

are sent for
further processing in another unit
such as a fractionation tower

A

Hydrocarbon liquids

118
Q

three types of catalyst bed

A

-Wire mesh
-Non reactive ceramic balls
-Catalyst pellets

119
Q

three types of trays

A

-Quench hydrogen ring
-Liquid collection tray
-Distribution tray

120
Q

is performed to remove impurities such as sulfur and
nitrogen.

A

Hydrotreating

121
Q

impurities such as sulfur and
nitrogen. These impurities are converted to..

A

ammonia and hydrogen
sulfide.

122
Q

Other impurities removed during this stage (hydrotreating) of the process
include

A

nickel, silicon, alkali metals, iron, arsenic, and vanadium

123
Q

need to occur prior to
the feed interacting with the hydrocracking catalyst, since the impurities
can reduce the catalyst activity. Often the feed is pretreated to remove
impurities

A

Hydrodenitrogenation and hydrodesulfurization

124
Q

Common hydrotreating catalysts include

A

cobalt molybdenum and silica- alumina.

125
Q

Hydrocracking consists of two main reactions

A

-Catalytic cracking
-The hydrogenation reaction

126
Q

uses
heat to break longer heavier molecules into shorter chains with the use
of a catalyst

A

Catalytic cracking

127
Q

These shorter chains are then saturated by adding hydrogen
in a hydrogenation reaction.

A

Catalytic cracking

128
Q

creates more
heat than is used in the cracking reaction, so the overall hydrocracking
reaction is exothermic. Due to the catalytic cracking occuring in the
presence of hydrogen, the hydrocracking reaction does not produce
coke like in a pure catalytic cracking reaction.

A

The hydrogenation reaction

129
Q

decreases over time due to fouling and coking

A

Catalyst activity

130
Q

is required to regenerate or replace the catalyst.

A

shutdown

131
Q

are used to allow for injection of quench hydrogen
for temperature control and more uniform mixing.

A

Multiple catalyst beds

132
Q

is a core component in a modern refinery and
processes about one third of the crude oil produced worldwide.

A

The Fluidized Catalytic Cracking or FCC unit

133
Q

It is particularly common in
North America due to its high yield of gasoline over diesel/kerosene.

A

The Fluidized Catalytic Cracking or FCC unit

134
Q

produces a combination of olefin rich
hydrocarbon vapours, gasoline, diesel and heavy fuel oil from a
feed of atmospheric / vacuum gas oil from the crude distillation
unit

A

The FCC unit

135
Q

is high molecular weight, long chain
hydrocarbons, w ith boiling points above 340 ֯C.

A

The feed to the FCC

136
Q

The process utilizes a ____ which lowers
the temperature that the long chain hydrocarbons will crack at.

A

powdered zeolite catalyst

137
Q

play an important role in the control of
the FCC operation.

A

The regen and spent slide valves

138
Q

They maintain a catalyst barrier between the
regenerator and reactor, preventing the mixing of the hydrocarbon
atmosphere in the reactor and the oxygen rich atmosphere in the
regenerator.

A

The regen and spent slide valves

139
Q

They are large hydraulically operated valves designed for the
severe conditions of the FCC unit.

A

The regen and spent slide valves

140
Q

operates at extremely
high temperatures between 1000-1400
°F (~540- 760 °C) so that the carbon on
the surface of the catalyst will autoignite. The only heat input into the
process during normal operation is
from this combustion heating the
surface of the catalyst

A

The regenerator

141
Q

is then fed to the reactor
standpipe where it mixes with the feed
stream of heavy gas oils and lift gas.

A

catalyst

142
Q

causes the long chain hydrocarbon
molecules to breakdown into shorter
molecules. This process is endothermic
so the reactor operates at a lower
temperature than the regenerator.

A

The heat and activity of the catalyst

143
Q

separate the
catalyst from the hydrocarbon stream
and return it to the regenerator.

A

Cyclones in the reactor

144
Q

must be
maintained in order to circulate the
catalyst from the system.

A

A positive differential pressure from the
regenerator to the reactor

145
Q

enters the reactor
standpipe
through feed nozzles to
atomize the liquid and
mix with the lift steam.

A

The feed stream of
heavy oil

146
Q

leaves
the regenator
and mixes with
the feed stream.

A

Regenerated
catalyst

147
Q

quickly
causes the long chain
hydrocarbons to
crack.

A

The heat and activity
of the catalyst

148
Q

cools the
process stream.

A

The endothermic
reaction

149
Q

disengage
the catalyst from
the hydrocarbon
vapour stream.

A

Cyclones in the
reactor

150
Q

exits the
top of the reactor.

A

A stream of cracked
hydrocarbon
vapours

151
Q

collects above
the spent slide
valve and
flows to the
regenerator.

A

catalysts

152
Q

enters the bottom
of the regenerator
and mixes with the
temperature
regenerator
spent catalyst. The
in the
is high
enough that it autoignites the catalyst.

A

air

153
Q

exits the
reactor

A

fuel gas

154
Q

the reactor product vapour enters the bottom of the fractionation tower

A

fractionation

155
Q

the fractionation tower splits the
vapour into different products

A

-Overhead gases which contain
a large amount of olefins

-Gasoline / naphtha cuts that
requires further treating

-Diesel

-Heavy fuel oils

156
Q

enter the
fractionation tower around 500°C
and begin cooling by mixing with
the slurry from the pump around.

A

the hot reactor vapours

157
Q

begin to
condense in the higher trays.
Products are drawn out and sent
downstream or are recycled back
to the tower to provide cooling.

A

less dense products

158
Q

flow through a condenser which causes water
and a gasoline product to drop out as liquids.

A

Overhead gases

159
Q

is separated
from the hydrocarbon liquid which is either sent downstream or
recycled back to the tower as a reflux stream

A

water

Process Engineering (4 decks)

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