1

Design considerations of hot oil system

Subhasish Mitra

Introduction:

Widely used in process industries especially in oil and gas plants as a heating medium, hot oil is

a heat transfer fluid (HTF) capable of transporting heat energy within a specified temperature

range. Use of HTF is attractive since it exchanges heat purely in liquid phase by sensible heat

transfer mode rather than by latent heat transfer mode in condensing vapour phase which

enhances system efficiency. Additionally, unlike steam, HTFs do not require high system

pressure to carry out high temperature operation owing to their low vapour pressure and high

boiling point which simplifies the system design. Some typical hot oil grades used in the

industries are Therminol, Dowtherm (A, G, J, Q, HT), Syltherm, Shell thermia, B.P. Transcal

etc. To achieve optimum fluid life, they need to be used only within the recommended bulk and

film temperature limits specified by the manufacturer. When not subjected to contamination, i.e.,

moisture, air, process materials, etc., and thermal stress beyond the specified limits, HTFs can

give years of service without significant physical or chemical change. A closed loop system

design is often chosen to cater heat duty to the process consumers through a fired heater or waste

heat recovery system. A minor make up although is required to the system as some quantity of

hot oil needs to be discarded from the system due to gradual thermal degradation. Efficient

design of this hot utility system is crucial for satisfactory performance of the respective process.

This article aims at elaborating the major design aspects of hot oil system such as sizing basis of

the equipment in the loop with illustrating calculations, general design considerations, PSV

selection criteria, control philosophy and system protection philosophy.

General description of the HTF system:

A hot oil system in general is a closed loop heating arrangement with a heat source typically a

fired heater or some kind of waste heat recovery units (WHRU) and heat sinks i.e. process heat

exchangers. Fig.1 illustrates such a system as per Shell design engineering practice (DEP) [1].

Hot the oil is filled up in the system by a make-up pump through a normally no flow (NNF) line

2

-

Fig. 1: Closed loop process flow diagram of hot oil system as per Shell DEP

Trim

cooler

N2

Filter

FC

UY

X

TC

PC

Split range

>

>

Expansion

vessel

WHRU

Trim

cooler

Pump out

cooler

HTF storage

tank

N2 To flare

To flare

Full flow

bypass

TC

Split

range

PDC

TC

Process

stream

Process

consumers

Spill over

bypass

+ -

Normally no flow

Circulation

pump

Make up

pump

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from the storage tank. To avoid contact with oxygen which eventually deteriorates hot oil

quality; the tank is kept under nitrogen blanket. The expansion vessel is usually kept at the

highest point of the system to vent any trapped gas. Stable level in the expansion vessel confirms

complete filling of the loop. Hot oil is circulated by the circulation pump through WHRU/heater

coils and heat is supplied to all process consumers. After heat exchange, hot oil is returned to the

suction of circulation pump. Supply temperature of the hot oil is controlled by a temperature

controller at the outlet of trim air cooler which operates on the both main line and bypass line

control valve through a split range control mechanism. Temperatures of the process streams are

maintained by controlling the hot oil flow rates. Process consumers can be completely bypassed

through the full flow bypass line during start up and partially bypassed by sensing the pressure

differential through the spill over bypass line when plant runs under turned down condition.

Under these circumstances, WHRU/heater load is dissipated in the trim cooler on the full bypass

line. Volume expansion or contraction of hot oil system is accommodated in the expansion

vessel. During maintenance of the system or any connected equipment in the loop, hot oil is

drained into the storage tank through the pump out cooler. Fig.2 describes similar process flow

diagram of hot oil system commonly employed in oil and gas plants. This scheme primarily

differs from previous one by introducing a fuel gas fired heater as the heat source and a separate

hot oil draining system. The BMS is an elaborate fuel gas flow control system to effectively

utilize the individual burner of the fired heater and usually supplied by the heater manufacturer.

During maintenance, hot oil is collected from the low point drains of the closed loop piping and

collected to an underground draining vessel through the dedicated draining network system. The

same vessel can be used for system filling purpose using the drain pump. Hot oil drums can be

emptied into this vessel through a filling connection. For complete cleaning of this drain vessel, a

vacuum truck connection is provided. A basic process control scheme is presented in Fig.2.

Outlet temperature of the fired heater is controlled by a temperature controller which controls the

fuel gas flow and hot oil flow to the heater. In case plant runs under turndown condition,

pressure of the system increases due to reduced demand of hot oil. The pressure controller senses

reduction of flow rate through pressure rise and bypasses the unused hot oil flow through the hot

oil trim cooler. Temperature at the downstream of trim cooler is controlled by manipulating the

motor speed.

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Fig. 2: A general process flow diagram of hot oil system commonly employed in oil and gas

plants

Normally no flow

Filter

FC

FC

TC

Fired

heater

Trim

cooler

TC

N2 To flare

Start-up line

PC

HTF drain drum

Expansion

vessel

Full flow

bypass

PCV

BMS

PCV

FG

FC

M

TC

Process

stream

Process

consumers

HTF storage tank

N2 To flare

HTF drain

drum pump

From hot oil

drain header

N2 To flare

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Sizing of equipment:

The major equipment used in a standard hot oil system are listed below,

• Hot oil expansion vessel

• Hot oil circulation pump

• Hot oil filter

• Hot oil start-up pump

• Fired heater and waste heat recovery units from gas turbine generator (GTG)

• Hot oil run down cooler

• Heat exchangers (Consumers)

• Hot oil storage tank

• Hot oil make up pump

• Hot oil drain drum and drain system

• Hot oil sump pump

Below various design considerations and sizing basis of the individual equipment are discussed.

Hot oil expansion vessel:

The expansion vessel allows for thermal expansion of the hot oil. Additionally this vessel is used

for venting low boiling point components generated in the system during normal operation and

purging out inert gas and water vapour during hot oil drying in start-up phase. The expansion

vessel minimizes the consequences of any upsets in the hot oil system operation. Following are

some significant aspects that need to be taken care of while designing this vessel,

• accommodating thermal expansion of the hot oil heated from minimum to maximum operating

temperature.

• maintaining the NPSHr for the hot oil circulating pumps under all operational circumstances.

• venting of possible residual water present in the circuit during start-up.

• allowing filling of equipment and during re-commissioning after shut down for maintenance.

The largest volume of the individual equipment that can be maintained while the hot oil system

remains in operation usually determines this inventory. The expansion vessel is connected to the

system return line on the pump suction side. The vessel is elevated so that the normal operating

level of the hot oil in the vessel is higher than the highest possible hot oil level in the system

(generally it is the fired heater or WHRU coils and typically 15 – 20 m from datum level). This

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will facilitate proper venting and provide sufficient NPSH for the loop circulation pump.

If this requirement is difficult to meet, a lower elevation may be selected but additional design

measures are then required to prevent vapour locking in the high points of the circuit. Hot oil

system pressure needs to be positive at the highest point to avoid any boiling and overflow into

the flare system. The expansion vessel is connected to the flare and equipped with an inert gas

(nitrogen or fuel gas) blanket to serve as a barrier between the hot fluid (usually operating at a

temperature above the flash and fire point of the hot oil) and the flare. The vessel’s vapour space

is prevented from contacting the atmosphere as it expedites aging of the hot oil and allow

moisture to enter the system during shutdown periods (these might create corrosive acid

compounds and a safety hazard). Only for operation at high temperatures, particularly

approaching or exceeding the boiling point of the hot oil, a positive pressure of at least 1 to 2 bar

above the vapour pressure of the hot oil (at this temperature) should be maintained otherwise a

blanketing gas pressure in the range of 200 to 300 mm wC (water column) needs to be

maintained. The nitrogen blanketing supply can be equipped with a split-range controller or self-

actuating PCVs and a non-return valve, which will regulate the nitrogen supply and its vent to

flare. A dead pressure zone is required between the inert gas supply pressure and the vent-to-

flare set pressure. In this dead zone, the pressure is not controlled and is allowed to float freely

while the nitrogen supply and vent-to-flare valves are both closed. This dead zone will reduce

nitrogen consumption and lower the starting point of venting low boiling point components. The

non-return valve prevents hot oil vapour and nitrogen back-flow into the nitrogen system in the

event of a pressure increase in the vessel.

A start up line between return line header and expansion vessel top is provided which can be

used to vent out air pockets in the loop during start-up by continuous pump circulation. During

operation, low boiling degradation products are vented on pressure control and routed to the

flare. The expansion vessel is equipped with a pair of safety relief valve capable of protecting the

system against over-pressure caused by events such as fluid degradation, contamination, mal-

operation, and overheating or tube failure in the process heat exchangers. The outlet of safety

relief valve is routed to flare.

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If the ambient temperature falls below the freezing point of the HTF or its degradation products

with the possibility of congealing, blanketing gas lines and safety relief lines along with

associated valves are required to be heat traced in order to prevent line plugging.

The expansion vessel serves the combined function of an expansion vessel and a knock-out

drum. It should have sufficient capacity to cater for various operating upsets in the system. The

expansion vessel allows for degassing of the hot oil and therefore should be fitted with a half

open pipe type inlet device. This vessel is designed based on volume expansion (loop hold up

consisting of pipe volume, fired heater/WHRU coil volume and all heat exchanger hold up) of

hot oil system of between maximum and minimum possible operating temperature. Volume

expansion (typically ~ 20%) is considered as difference between specific volume (m3/kg) i.e.

inverse of specific gravity of hot oil at maximum and minimum operating temperature of the

system which is required to be accommodated between Low liquid level and High liquid level of

the expansion drum. An additional 20% is added to cater for various operating upsets in the

systems such as vaporization of residual water in the system and a tube burst.

The inventory between LL and LLLL should be 25% of the vessel volume or 150 mm whichever

is more while HHLL is fixed at 150 mm above HLL. Vessel diameter can be found out by setting

HHLL at 80 – 85% of vessel ID assuring that 75% vessel volume gets accommodated within

HLL. The remaining volume of the vessel volume allows for gas-liquid separation and is filled

with inert gas.

A sizing calculation for expansion vessel is illustrated below.

Hot oil expansion drum calculation:

Piping volume = π(Dp/2)2 Lp where Dp = pipe ID, Lp = piping length according to plot plan.

As per P&ID and plot plan, total piping hold up volume: 65.5 m3

Total piping volume with 10% margin = (65.5 x 1.1) = 72 m3

(Margin can be increased up to 30% if major uncertainty persists in the plot plan)

Equipment hold up volume = 15.1 m3 (this comprises of volume of heater coil and heat

exchangers. Heat exchanger volumes are calculated as follows considering HTF flows in the tube

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side. Shell volumes need to be considered otherwise for hold up calculation if HTF flows in shell

side),

nπ (D/2) 2

L where Dt = tube ID, Lt = tube length n = number of tubes.

So, Total system volume = (72 + 15.1) = 87.1 m3

Consider following physical properties for commercial grade HTF (Table 1)

Expansion volume from cold start up to normal operation is considered as design case for the

vessel. A check case is performed to ensure adequate design margin in case of process upset.

Table 1: Density variation with temperature of a commercial grade HTF

Mass of total hold up (density at min op temp) = (87.1 x 973) = 84748.3 kg 84766.7 kg

Volume of oil required based on density at max op temp = (84748.3/868) = 97.6 m3

Expansion volume: (vol at max op temp – vol at min op temp) = (97.6 – 87.1) = 10.5 m3

With 20% margin on expansion volume = (10.5 x 1.2) = 12.6 m3.

The check case is considered to see adequacy of the given margin. Volume of oil required based

on density at min op temp = (84748.3/868) = 97.6 m3

Volume of oil required based on density at max op temp = (84748.3/854) = 99.2 m3

Expansion volume: (vol at max op temp – vol at min op temp) = (99.2 - 97.6) = 1.6 m3

Max expansion of volume including the process upset = (10.5+1.6) = 12.1 m3

can be

accommodated within the 20% margin. So design is adequate.

Let’s select an expansion vessel of configuration 2.2 m (ID) x 7.6 m (L) for this service. An L/D

ratio of more than 3 is considered in the selection.

Temperature

Design case Check case

Temp oC Density kg/m

3 Temp

oC

Density kg/m3

Min operating temp. 60 973 210 868

Max operating temp. 210 868 230 854

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We need to ensure that the design expansion volume should be accommodated within the

operating liquid levels i.e. HLL and LL. Levels are adjusted within the controllable range to

accommodate the desired liquid volume.

Volumes within the levels are calculated by adding part volume of cylinder and head.

Part area of cylinder between BTL and LLLL = D2/8(2α-sin 2α)

where α = cos-1

((D/2-LLLL)/ (D/2))

Part volume of cylinder = D2/8 (2α-sin 2α) L where L = length of cylinder

Part volume of the head (2: 1 SE) = π/2(DH2/2 – H

3/3)

Similarly volume occupied between all the levels are calculated and tabulated below,

Table 2: Liquid levels to check design volume within the selected dimensions

Levels Height (m) Total volume

m3

Diameter 2.2 30.28

HHLL 1.76 26.03

HLL 1.55 22.85

NLL 0.82 10.25

LLL 0.66 7.59

LLLL 0.15 0.87

The above calculation shows that between HLL and LLL a volume of 15.26 m3 is provided

which is sufficient for the calculated expansion volume with margin (12.6 m3). Thus the selected

diameter and length of expansion vessel are suitable to meet the design requirement. Normal

level is based on expansion volume for design case since vessel will be operating at 2100C max

however it can lie anywhere between HLL and LL preferably at 50% of the range depending on

the operating conditions.

Hot oil circulating pumps:

Hot oil circulating pumps are centrifugal pumps 1 X 100% typically arranged as 1 working + 1

stand-by unless there is a clear justification for 3 X 50 % capacity to maintain the closed loop

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circulation through fired heater or WHRU or in combination of both as per project requirement.

Flow rate of this pump is designed based on heat duty of all the consumers typically all the

reboilers. 10% margin is applied on total calculated flow rate. For line sizing refer Table 8. If

continuous filtration is applied via a bypass across the pump (10% of total flow max), the

capacity of the pumps should include this additional flow. In the event of low hot oil pressure,

the spare pump should take over automatically. The stand-by pump should be maintained in a

pre-heated state in order to avoid thermal shock when starting by providing the bypass across the

discharge check valve. Due to prolonged operation, hot oil may degrade generating some lower

boiling point components which lead to higher vapour pressure of the hot oil in the system than

the pure hot oil as specified by the manufacturer. The rise in vapour pressure lowers the NPSHa.

To determine the NPSHa to the pump, it is assumed that the vapour pressure of the hot oil is

equal to the pressure in the expansion vessel at normal operating temperature. If necessary, the

height of the drum is raised to ensure that there is sufficient NPSHa. While calculating NPSHa, it

is wise to keep 1 meter margin to account for any unforeseen pressure loss. NPSHr is specified

by the pump manufacturer and should be less than NPSHa by at least 1-2 ft margin. Discharge

pressure of the pump is obtained by summing up expansion vessel pressure and all the pressure

drops incurred in the discharge line including line, fittings, equipment and valves. A general

condition applies to all pumps to be capable of cold filling of the system.

Hot oil filters:

Organic HTFs degrade over time due to thermal cracking, oxidation and contamination. The by-

products of degradation are sludge and coke. Contaminates can also include dirt, sand, dust, mill

scale, and slag from piping that accumulate during down-time maintenance or from installation.

Often a Y type or basket type strainer is installed at the pump suction. Typically the strainer

contains 100 mesh size stainless steel woven wires. These are designed to protect the pump and

flow meter.

Installing filter in the loop has following benefits

• Removal of particulates that can degrade the oil

• Maintains viscosity of fluid longer by reducing sludge build-up

• Maintains thermal efficiency of system longer and reduces energy cost

• Extends HTF life

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• Reduced maintenance costs by protecting pumps and valves from contaminates

The strainer should be cleaned regularly to prevent pump cavitation which can cause mechanical

seal failure. For continuous filtration purpose, hot oil loop generally is provided with 1 X 100%

filter in 1 working + 1 stand by arrangement at a side stream bypass line around circulation pump

discharge. A partial flow rate up to 10% max is routed through the filter to screen thermal

degradation product. A differential pressure indicator across the filters in the bypass line is fitted

to monitor fouling in the system. Filters need to be equipped with 75 µm to 100 µm elements

during commissioning and initial operation, and subsequently these are replaced with 10 µm to

20 µm elements unless the hot oil manufacturer of makes more stringent recommendations or

project has a different requirement.

Hot oil start up pump:

1 X 100 centrifugal pump without any stand by is provided in case WHRUs are used as heat

source in the closed loop hot oil system. This pump is supplied power from emergency diesel

generator as it is required to maintain a small circulation flow through WHRU coils before the

GTGs start. This is an essential requirement as WHRU coils are not advisable to run dry while

GTGs are running because of thermal damage possibility. This pump is sized to cater to 5%

(max) of total system flow rate in order to maintain a velocity of about 1 m/sec and should have

same discharge pressure to that of circulation pump.

Fired heater and WHRU:

Generally natural draft or mechanical draft (induced or forced) fuel gas fired heater is used as

heat source in the hot oil system. If fired heater is the only heat source in the loop then its duty is

calculated summing up all the consumers’ duty with a design margin of 10-15%. A heater

efficiency of 80 - 85% is considered to figure out design heat duty. In some cases, fired heater

may be required as only as stand by when most of the heat input into the system is recovered

from heat recovery coils in flue gas stack of GTG. Flue gas leaves GTG stack at a very high

temperature (500 – 600°C) and by controlling flue gas damper opening, this heat can be utilized

in the hot oil loop. When WHRU coils are the prime source of heat, heat recovery coils are sized

based on operation philosophy of the GTGs. Following calculation illustrates estimation of fired

heater heat load.

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Heat load of fired heater

The following hot oil consumers are identified in a typical onshore oil and gas plant. The heat

loads are calculated in HYSYS and listed below. All the designed figures include 10% margin

unless otherwise specified.

Table 3: Heat load of hot oil consumers

Equipment Thermal Load, kW

Normal Design

Stabilizer reboiler 1066 1173

Deethanizer reboiler 2821 3103

Debutanizer reboiler 1569 1726

Molecular sieve

regeneration gas heater

and regeneration gas

super heater

550 605

Total 6006 6607

So, total heat duty of the fired heater is 6607 kW. The heat duty will proportionately increase if

there are parallel production trains. Consequently separate fired heater may be required if the

total heat requirement cannot be met by a single heater. Fuel gas requirement to fired heaters can

be estimated as follows. Consider, low pressure fuel gas is available at 5 barg pressure and 450

having LHV of 44380 kJ/kg. The LHV depends upon the fuel gas compositions and various

simulation cases need to be analysed to find out the lowest LHV to be considered for the design

case. Assuring 85% thermal efficiency of the heater, fuel gas flow requirement is (6607 x

3600)/(44380 x 0.85) = 630.5 kg/hr

Hot oil trim cooler:

In order to improve operation and increase the flexibility of the hot oil system, a trim cooler is

installed in the loop. This cooler serves the purpose of rejecting heat during heater start-up or

when consumer duties in the loop suddenly reduce because of decrease in plant throughput or

some inadvertently caused mal-operations. Typically, an air-cooled heat exchanger is selected.

The cooler should be capable of rejecting the minimum heater duty at stable operation (heater

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turn-down is ~ 25%, usually specified by the manufacturer) or highest process consumer duty in

the system, whichever is more. Flow rate through cooler can be estimated by the oil temperature

at cooler outlet which is normally fixed at 600C. In addition to 10% margin on flow rate, 10%

margin on thermal duty should also be provided by means of surface area.

Heat Exchangers (Process consumers):

In systems with heat users operating at pressures above that of the hot oil system, the piping

design should take into account of all hazards caused by a tube rupture inside this equipment.

Hot oil distribution headers and piping to consumers are sized for 110 % of the maximum flow.

The spill over lines and control valves are sized for the flow of the largest consumer to allow for

a sudden block-off of the heat user. Manual bypass lines are sized for 100 % flow. The following

usually apply except for double-pipe heat exchangers:

If the process pressure exceeds the hot oil system pressure, the preferred arrangement is to ensure

a free flow (no valves) from the consumer (heat exchanger) to the expansion vessel. If valves are

installed, the following alternatives may be applied:

• The hot oil system is designed for the higher pressure (2/3rd

rule)

• Overpressure protection devices (safety relief valves or rupture disks) are installed at the

outlets of the affected heat exchangers with relief to flare via a liquid separator.

If designed and operated properly, hot oil systems can be considered to be non-fouling, so U-

tube type heat exchangers may be applied if the hot oil flows inside the tubes. This is cheaper

than floating head type heat exchangers and significantly reduces the risk of leakage and,

consequently, contamination of the hot oil or process fluid. For the design specification of hot oil

systems a fouling resistance of 0.00017 m2/kW is taken. Effects of leakage of hot oil into the

process or vice-versa are reviewed and double welded tube-to-tube sheet connections are

specified, if required. All heat exchangers are equipped with hard piped drains and vents to allow

the hot oil to be drained into the drain drum. To speed up the evacuation, a nitrogen purge point

is installed to allow a hose connection from a nearby utility station.

Hot oil storage tank:

The hot oil storage tank is sized to have a working volume equal to the full inventory of the

system (pipe volume as per plant lay out, fired heater/WHRU coil volume and heat exchanger

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hold up), plus an additional 10 % volume to accommodate make-up of losses caused by venting

and mechanical leaks. On plants with multiple parallel trains it may be justified to reduce the

storage tank capacity to hold the inventory of a single train only unless it is feasible that these

trains must be drained at the same time.

The minimum fluid level in the tank is set to ensure sufficient NPSH for the make-up pump. If

the ambient temperature falls below the hot oil minimum pumpability temperature, it may

congeal and plug the pipelines. Special design considerations need to be applied for such

congealing service. In this circumstance, the tank is heated, preferably electrically, and the

suction line to the pump is heat-traced. The storage tank is equipped with inert (nitrogen/fuel

gas) gas blanketing with self-actuating PCVs connected to flare or vent to atmosphere at safe

location to serve as a barrier between the fluid and the atmosphere to limit aging (oxidation) and

moisture ingress.

During shipment, air bubbles can be entrained in the fluid. If the cold fluid is immediately

pumped into the system, the air bubbles can cause pump cavitation. It is advisable that the fluid

should be near room temperature prior to charging the system. The drums may be stored in a

warm room to bring the fluid up to room temperature. The warmer the fluid, the more easily it

can be pumped into the system. A complete spare hot oil inventory should be made available to

replace a total loss of hot oil from the system due to leakage or contamination by a process fluid.

Hot oil make-up pump:

1 X 100% centrifugal pump without any stand by is provided for hot oil make up service. This

pump should fill up the entire hot oil system from hot oil storage tank. The pump is sized for

complete fill up of the system within 8 hours to 24 hours (max). In case, hot oil storage tank is

not in the scope of the project then hot oil sump pump should act as make up pump. Discharge

head of the pump is estimated based on the elevation of the expansion vessel.

Hot oil drain drum and drain system:

A hard piped dedicated closed drain system for maintenance purposes is provided. The purpose

of a hot oil drain system is to collect hot oil inventory in a controlled manner from piping and

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equipment prior to maintenance so that it can be returned later to the system for re-use or

controlled disposal, as required. Since drainage of hot oil in hot condition to the drain drum is

not envisaged, it is cooled prior to entering the storage drum by the run down cooler or via the

process. The hot oil inventory can be cooled by alternative means such as with a column reboiler

on hot oil with the column operating on total reflux and thus using the overhead condenser as

indirect means of cooling the hot oil in the system. In systems with a fired heater, the combustion

air fans can be used to cool down the furnace while hot oil is circulated through the heater tubes.

A drain system is intended to reduce spillage of hot oil, which could lead to HSE incidents. The

drain piping should be installed underground and be free flowing to a closed collection vessel.

Because the installation of drain piping is underground, the drain system is solely for the

collection and draining of cooled down hot oil. The drain header is routed as close as possible to

the drain points to reduce the length of small bore drain piping. Where a free flow of drained hot

oil is not feasible, then an above ground nitrogen purge assisted drain line may be considered. A

suitably sized vent is made on the collecting drum to vent the nitrogen to safe location at

atmosphere or to flare. The collection drum is normally inert gas (nitrogen/fuel gas) purged to

avoid ingress of air and/or moisture from the flare, and be located in a (dry) pit for secondary

containment. The collection drum is sized to receive the hot oil volume from the largest

consumer or group of consumers in the loop that can be taken out of service at the same time

with margin (25% max). The collection vessel is provided with a pump for returning the hot oil

to the hot oil storage tank or into main system itself in case hot oil storage tank is not in project’s

scope. A connection is provided for vacuum truck to empty out the drum for hot oil disposal. If

the collection vessel is also used for make-up of fresh hot oil into the system from storage drums,

a filling connection is made available for connecting a portable drum unloading barrel pump.

This connection may be combined with vacuum truck connection.

Hot oil sump pump:

Hot oil sump pump is a vertical submersible 1 X 100% centrifugal pump placed inside the hot oil

drain drum. In case, hot oil storage tank is not in the scope of the project, the sump pump can be

utilized as the make-up pump and will follow the same sizing basis.

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Line sizing:

To design the circulation loop hydraulics, total hot oil flow rate needs to be estimated. Consider

the following physical characteristics of the commercial Shell Thermia B HTF (Table 4). Supply

temperature of the hot oil is fixed at 2600C (Tsupply), little above fire point ensuring that

maximum heat transfer is possible without degrading the quality subject to maximum permitted

bulk temperature.

Table 4: Physical characteristics of Shell Thermia B HTF

Unit Standard property values

Density at 15 deg C kg/cu.m ISO12185 868

Flash point PMCC deg C ISO2719 210

Flash point COC deg C ISO2592 220

Fire point COC deg C ISO2592 255

Pour point deg C ISO3016 -12

Kinematic viscosity

at 0 deg C

at 40 eg C

at 100 deg C

at 200 deg C

sq.mm/s ISO3104

230

25

4.7

1.2

Initial boiling point deg C ASTM D86 >355

Autoignition temperature deg C DIN 51794 360

neutralization value mgKOH/g ASTM D974 <0.05

Ash (Oxid) %m/m ISO 6245 <0.01

Carbon residue (Conradson) %m/m ISO 10370 0.02

Copper corrosion (3h/100 deg C) ISO 2160 class I

Coefficient of thermal expansion 1/deg C 0.0008

Return temperatures of hot oil streams (Table 5) have been calculated after careful consideration

to approach temperature in the design of respective heat exchangers assuring no temperature

cross.

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Table 5: Hot oil return temperatures from process heat exchangers

Equipment

Hot oil return

temperature 0C

(Treturn)

Stabilizer reboiler 165

Deethanizer reboiler 158

Debutanizer reboiler 158

Regeneration gas heater and

Regeneration gas super heater 190

Average specific heat of hot oil (Cp) is found out at supply and return temperature from Table 6

by interpolation (Fig.3).

Table 6: Physical properties of Shell Thermia B HTF

Temperature (°C) 0 20 40 100 150 200 250 300 340

Density (kg/cu.m) 876 863 850 811 778 746 713 681 655

Specific heat

capacity (kJ/kg/K) 1.809 1.882 1.954 2.173 2.36 2.538 2.72 2.9 3.05

Thermal

conductivity

(W/m/K)

0.136 0.134 0.133 0.128 0.13 0.121 0.118 0.11 0.11

Viscosity (cP) 253.73 65.43 25.52 4.06 1.7 0.954 0.607 0.43 0.33

Fig.3: Linear interpolation of HTF specific heat with temperature

y = 0.0036x + 1.8087

R² = 1

0

0.5

1

1.5

2

2.5

3

3.5

0 100 200 300 400

Sp

. h

eat

(kJ

/kg

/K)

Temperature (deg C)

HTF specific heat

18

Solving the following heat balance equation mass flow rate of hot oil (MHTF) through each heat

exchanger can be found out.

MHTF x Cpavg x (Tsupply – Treturn) = QHX (design duty of heat exchanger)

Hot oil flow rate through each heat exchanger is listed in Table 7.

Table 7: Hot oil usage in process heat exchangers

Equipment Design hot oil

flow (kg/h)

Stabilizer reboiler 17265

Deethanizer reboiler 42763

Debutanizer reboiler 23783

Regeneration gas heater and

Regeneration gas super heater 11886

Total 95697

With the total flow rate obtained from Table 7, following sizing criteria given in Table 8 can be

used to decide various line segments diameters of the circulation loop with 10% design margin.

HTF present in the loop is considered as boiling liquid and stricter sizing criteria are imposed on

sizing of pump suction line.

Table 8: Line sizing criteria

Service

(Boiling liquid)

Line size

(inch)

Maximum

velocity (m/s)

Pressure drop

Normal Max

(bar/100m) (bar/100m)

Suction ≤ 2 0.6 0.01 to 0.05 0.09

3 – 10 0.9 0.01 to 0.05 0.09

12 – 18 1.2 0.01 to 0.05 0.09

20 1.5 0.01 to 0.05 0.09

Discharge

∆P ≤ 50 bar g

2 – 18 1.5 to 4.5 0.35 0.45

>20 6 0.35 0.45

Hot oil drain lines should be designed for gravity driven flow with liquid velocity <0.5 m/sec.

19

Control philosophy:

Hot oil system control scheme, in case to case basis may look little different based on project

requirement however the control objective of the system is to allow stable operation at

continuous turndown of heat demand from design heat duty to zero. Control scheme of

individual equipment is discussed below.

Expansion vessel is provided with inert gas blanketing. Depending on project requirement this

can be fuel gas or nitrogen. Blanketing gas pressure inside the vessel can be controlled by a split

range pressure control arrangement which contains a pressure controller on the vessel and

control valves on the incoming and outgoing blanket gas. Incoming gas stream pressure control

valve receives 0 – 50% output of the controller while outgoing gas stream pressure control valve

receives 50 – 100%. A cheaper option of self-actuated PCV arrangement instead of pressure

control valve may also be used.

Circulation pump is provided with a discharge flow (if performance curve is flat) or pressure

controller (if performance curve is drooping) on bypass loop which protects the pump from

running at shut-off condition when ESD or manual valves at downstream of hot oil supply line

get closed due to some interlock or inadvertent operation.

Fired heaters or WHRUs or a combination of both are provided with individual flow controller

on hot oil inlet line. Outlet streams of are provided with temperature controller which senses any

rise in temperature (due to decrease in heat duty of consumers) and controls fuel gas firing rate

(for fired heater), damper position to control flue gas flow (for WHRUs) and flow through

rundown cooler to maintain temperature of hot oil return line.

Proper control of hot oil run down cooler serves a critical purpose when heat demand from, and

hot oil flow to the heat consumers decreases. Cooler may have different control scheme if fan

blade pitch control is available. A temperature controller at downstream of cooler senses the

temperature and controls the blade pitch to vary rpm in order to maintain the return line

temperature. The same control can be achieved with variable frequency drive subject to cost

implication of the project. The most cost effective control however is through a bypass line flow

20

control through cooler when air cooler fans run at a fixed rpm.

Hot oil storage tank and drain vessel are provided with inert gas blanketing similar to expansion

vessel hence similar control scheme applies. The drum should have separate level transmitters

for control and trip action of the sump pump. Hot oil sump pump can be provided with auto start

option to start at high level and stop at low liquid level. This would prevent the possibility of

over filling the drum while draining from multiple equipment in the loop.

System protection:

For safe operation, some protection measures are employed for intrinsic safety of the system

which may vary from project to project as per specific requirement or philosophy. For ultimate

safety of the system, supply of both hot oil and LP fuel gas are cut off. For WHRU, dampers are

shut off. Expansion vessel is provided with LLLL and HHLL trip. At HHLL, the make-up pump

trips while at LLLL, the entire hot oil system triggers a shutdown. Hot oil circulation pumps are

provided with LL suction pressure trip which triggers a system shutdown. Additionally, all

pumps should trip on LL seal pressure and HH current. Hot oil heater/WHRU inlet and outlet

line are provided with ESD valve which closes when HH temperature or LL flow is sensed on

the outlet hot oil stream from heater/WHRU causing system shutdown. For fired heater,

additional safety interlocks i.e. HH flue gas temperature, HH fire box pressure etc. are advised

by the manufacturer. Hot oil run down cooler is provided with HH vibration trip. If automatic

louvers are provided then upon loss of instrument air signal, louvers should remain in the last

position prior to loss of signal. The storage tank is provided with LLLL and HHLL trip. At

HHLL, hot oil sump pump trips while at LLLL, the make-up pump trips. Hot oil make-up pump

trips on LLLL of hot oil storage tank and LL suction pressure. The pump also trips on HHLL of

expansion vessel. Hot oil sump pump trips on LLLL of hot oil drain drum and on HHLL of

expansion vessel in case it is used as make up pump.

Pressure safety valves are installed in the loop as safety measures as deemed necessary. Table 8

summarizes various relief scenarios commonly encountered in the hot oil circulation loop. Sizing

of the PSVs are done as per API guidelines [3,4].

21

Table 8: Relief scenario analysis of various equipment in the hot oil loop

Equipment Relief scenario No. of safety valve Remarks

Expansion vessel Blanketing gas PCV failure

Tube rupture of process heat

exchangers

2 (1W + 1S) Tubes rupture case

need to be considered

when hot oil circuit

pressure is more than

the process stream

pressure.

Discharge is routed to

LP flare/ground flare

Filter Fire

.

2 (1W + 1S) Discharge is routed to

LP flare/ground flare

Hot oil inlet line

to fired heater or

WHRU

Thermal expansion

1 Discharge is routed to

LP flare/ground flare

Drain drum Blanketing gas PCV failure

Fire

2 (1W + 1S) Discharge is routed to

LP flare/ground flare

Material Selection:

Generally, carbon steel is used in most case. Aluminium, brass and bronze should not be used

however copper and copper alloy can be adopted in the place of no air contact. Austenite

stainless steel should not be used if chlorinated contamination is envisaged.

System insulation:

The entire system should be insulated to prevent heat loss however selection of insulation needs

special caution. Due to low surface tension and low viscosity at operating temperatures, hot oils

penetrate through joints, gaskets and seals. This results in leaks that can lead to accumulation of

fluid inside insulation. Insulation materials such as mineral wool or similar, when saturated with

organic hot oils, can cause slow exothermic oxidation starting at temperatures above 250°C. The

large internal surface area, poor heat dissipation and the possible catalytic activity of the

insulation material may cause significant temperature build-up within the insulation mass. Such

22

slow reaction may progress undetected and may lead to unsafe situations such as sudden fires

when cladding is damaged or opened for maintenance. Non-absorbent insulation (e.g. foam

glass) or no insulation at all is used at potential fluid ‘creep’ locations (instrument connections,

valve stems, flanges and joints).

Periodic sampling:

Hot oil is subject to thermal degradation due to continuous operation at elevated temperature. To

ensure that physical properties of the hot oil remain stable or if the system requires fresh make

up, periodic analysis hot oil samples can helps in monitoring health of the system. Contaminants

can also catalyse fluid degradation and result in severe operating and equipment problems. The

most common contaminant in HTFs is water which can be determined by the Karl Fischer test.

The test data collected over time can be used along with the operating history to obtain a

complete system analysis. This allows corrective action to be implemented before the fluid life

or equipment efficiency is compromised. The sample must be taken from a “live” part of the

system, preferably at the heat exchanger or the circulating pump and not from some stagnant

parts like expansion or drain vessel. Also, it is important that the sample is put directly into the

sample container to avoid any contact with air or moisture.

System cleaning:

Irrespective of whether the system is new or old, there are many contaminants that can find their

way into heat transfer systems. Hard contaminants such as weld slag, spatter and mill scale can

damage pump bearings, seals and control valves. The mill scales can promote fluid oxidation.

"Soft" contaminants such as protective lacquers and coatings, oils and welding flux are thermally

unstable and can cause degradation of the fluid. Minute presence of water in the system can

cause pump cavitation and corrosion and if trapped in a "dead leg" and hit by high-temperature

oil. Water rapidly flashes to steam and damages the system by over-pressurization. The system

is cleaned before the new hot oil is introduced. Provisions are made for blowing out the system

with nitrogen to ensure the system is dry prior to start-up.

Nomenclature:

BMS: burner management system

23

BTL: bottom tangent level

ESD: emergency safe shutdown

FG: fuel gas

GTG: gas turbine generator

HH: high high

HHLL: high high liquid level

HLL: high liquid level

HTF: heat transfer fluid

HSE: health safety environment

LL: low low

LLL: low liquid level

LLLL: low low liquid level

NLL: normal liquid level

LP: low pressure

NPSHa: net positive suction head available

NPSHr: net positive suction head required

PCV: pressure control valve

S: standby

W: working

WHRU: waste heat recovery unit

Literature cited:

1. Shell Design Engineering Practice, DEP 20.05.10-GEN.

2. IPS–E-PR-410, Engineering standard for process design of hot oil and tempered water circuits,

original edition, March 1996.

3. Guide for pressure - relieving and depressuring systems, API recommended practice 521,4th

edition, March 1997.

4. Sizing, selection and installation of pressure-relieving devices in refineries, part- I- sizing and

selection, API recommended practice, 520, 7th edition, January 2000.

24

Acknowledgement:

Author would like to gratefully acknowledge contributions of process department of Petrofac

Engineering (India) Ltd. and Petrofac E&C (Sharjah) through valuable discussions as input to

this work.

Brief profile:

Subhasish Mitra (email: subhasish.mitra@uon.edu.au), currently is a research scholar at

University of Newcastle, NSW, Australia. Prior to joining the PhD program, he has served as a

process engineer over 7 years in the domain of process development, process troubleshooting

and process design in nuclear, petrochemicals and oil & gas industries. He holds an M.Tech

(chemical engineering) from Indian Institute of Technology, Kanpur and a B.Tech (chemical

engineering) from Haldia Institute of Technology, India. He is an associate member of the Indian

Institute of Chemical Engineers (IIChE).