magnetrol o&g

I N D U S T R Y A P P L I C A T I O N S S E R I E S

A Guide to Level Instrumentation for Onshore/Offshore Oil Processing

APPLICATION PAGE

1. Production Fluid Storage 3

2. Chemical Injection 3

3. Wellstream Separator 4

4. Crude Dehydration 5

5. Crude Desalting 5

6. Crude Degassing 6

7. Water Processing 6

8. Storage Tanks 7

9. Vapor Recovery 7

Level & FlowApplications forCRUDE OILPROCESSINGLevel and flow controlsin these applications arecrucial for both processcontrol and safetyshutdown systems.

Plant Inlet

Crude StreamLevel Applications

Skim Tanksand Vessels

Sumps

Primary Water Treatment

Fluid Tanks

Desalting

Collection Tanks

Separation

Crude Dehydration

TestSeparation

3

1

2

Coalescers

Recycle Gas/Flare

Degassing

Crude Collectionand Storage Tanks

4 8

Natural Gas Processing

Natural Gas processing is found inmany crude oil drilling and processingoperations. For information on levelapplications for natural gas processing,see our Natural Gas Processingbrochure.

To disposalTo reservoir

Secondary Water Treatment

5

Coalescers

Flotation Units

Chemicals

7

Flow Applications:

6

8

Flow controls forpumps, compressors,and liquids are foundthroughout crude oilfield operations.

Water StreamLevel Applications

Level Applications:

8

7

Flow Alarm:ThermatelModel TD2ThermalDispersionFlow Switch

Continuous Gas Flow:ThermatelModel TA2ThermalDispersionMass FlowTransmitter

Vapor Recovery9

NOTE: The actual nature and number of stepsin crude oil processing most often dependsupon the source and makeup of the wellheadproduction stream. In some cases, several ofthe steps shown in the schematic below maybe integrated into one unit or operation, per-formed in a different order or at alternativelocations, or not required at all.

Natural Gas

Water

Water

2

PRODUCTION FLUID STORAGE1INSTRUMENTATION

CHEMICAL INJECTION2

INSTRUMENTATION

Application: Chemical agents employed in crude process-ing include drilling fluid additives, methanol injection forfreeze protection, glycol injection for hydrate inhibition,produced water treatment chemicals, foam and corrosioninhibitors, de-emulsifiers, desalting chemicals, and dragreduction agents. Chemicals are frequently administered byway of chemical injection skids.

Challenges: Level monitoring controls chemical inventoryand determines when the tanks require filling. The carefulselection and application of level controls to chemical injectionsystems can effectively protect against tanks running out ofchemicals or overfilling.

Chemical Injection Skid

Application: A variety of chemicals are typically stored inthe field or processing facility to expedite processing timeby preconditioning an inlet fluid. These fluids may first enterinto a hold tank to allow upstream solids and liquids time toseparate prior to production, which allows the facility tobetter handle upset conditions without stopping production.Stored additive chemicals include dispersants, flocculants,surfactants, glycols, diluents and rust inhibitors.

Challenges: Fluids are typically stored in a series of out-door steel tanks. The tank fluid volume should be continu-ously monitored since level variations may lead to upsets.Tanks contain agitated media with suspended solids thatcan coat floats, displacers and probes.

Continuous Leveland Interface Level:Eclipse Model 705 GWRTransmitter with EnlargedCoaxial Probe; or Pulsar

or R82 Non-contacting,Pulse Burst RadarTransmitters

Point Level:Echotel Model 961Ultrasonic Switch;THERMATEL ModelTD1/TD2 Switch;Tuffy II Float-actuated Switch

Continuous Level:ECLIPSE Model 705Guided Wave RadarTransmitter; or Jupiter

MagnetostrictiveLevel Transmitter

Visual Indication:Atlas or Aurora

Magnetic LevelIndicators can besupplied withswitches ortransmitters

Storage Tanks

3

Point Level:Thermatel Model TD1/TD2Thermal Dispersion Switch;or Model A15 SeriesDisplacer-ActuatedLevel Switch

WELLSTREAM SEPARATORS3INSTRUMENTATION

Application: Separators are large drums designed toseparate wellstreams into their individual components.They are commonly designed to separate two-phase(gas/liquid) or three-phase (gas/crude/water) wellstreams.Separators are also classified according to horizontal orvertical configuration (see below), operating pressure,turbulent or laminar flow, and test or production separation.

Challenges: Interface level measurement will actuate avalve to adjust vessel level. An emulsion layer along theoil/water interface can contaminate the oil with water orthe water with oil. Foaming along the gas/liquid interface,if entrained, can cause liquid carryover or gas blowby.

Oil Field Separator

Point Level:Series 3 Float-actuatedExternal Cage LevelSwitch; THERMATELModel TD1/TD2Switch; Model A15Series Displacer-Actuated Level Switch

Continuous Leveland Interface Level:ECLIPSE Model 705;JUPITER Magneto-strictive LevelTransmitter;or E3 Modulevel

Displacer Transmitter

Visual Indication:ATLAS or AURORAMagnetic LevelIndicators canbe supplied withswitches ortransmitters

Vertical (right): Vertical separators can accommodate large surges ofliquids. They are well suited for high sediment loads; conical bottoms aresometimes attached for large volumes of sediment. Vertical separatorsare preferred when wellstreams have large liquid-to-gas ratios. Theseseparators occupy less floor space than horizontal types and are oftenfound on offshore platforms where floor space is at a premium.

Horizontal (below): These separators are well suited for three-phaseseparation because of their large interfacial area between the two liquidphases. Horizontal types are preferred when wellstreams have high gas-to-oil ratios, when wellstream flow is more or less constant, and whenliquid surges are insignificant. These separators also have a muchgreater gas/liquid interface area, which aids in the release of solution gasand in the reduction of foaming.

TWO PRINCIPAL TYPES OF SEPARATORS

NATURAL GAS

WATER

GAS OUT

OIL OUTWATER OUT

OILEMULSION

GAS OUT

OIL OUT

NATURAL GAS

WATER

WATEROUT

OIL

EMULSION

WELLSTREAMIN

VERTICALHORIZONTAL

Flow Indication:ALARM:THERMATELModel TD1/TD2Flow Switch;CONTINUOUS:THERMATELModel TA2 MassFlow Meter

WELLSTREAMIN

4

CRUDE DEHYDRATION4INSTRUMENTATION

CRUDE DESALTING5

INSTRUMENTATION

Application: Not all water is removed from crude oil duringthe first stage of gravity separation. Separated crude maycontain up to 15% water which exists in an emulsified formthat is difficult for a separator to remove. The oil and wateremulsion must be broken down so that the water can beremoved before the crude is shipped. De-emulsificationprocesses are accomplished using chemical agents suchas glycol and heat.

Challenges: Level control is found on two-phase andthree-phase water knockout drums, heater treaters andchemelectric dehydrators. Interface measurement is criticalin dehydration as it keeps the water-emulsified oil fromflowing over the separator weir.

Knock-out Drum

Point Level:Series 3 Float-Actuated ExternalCage LevelSwitch

Continuous Leveland Interface Level:ECLIPSE Model 705Guided Wave RadarTransmitter; or E3MODULEVELDisplacer Transmitter

Visual Indication:ATLAS or AURORAMagnetic LevelIndicators can besupplied with switchesor transmitters

Application: Salt in the crude stream presents serious cor-rosion and scaling problems, and must be removed. Salt isdissolved within the remnant brine of the crude oil.Desalting removes both salt and the residual free water.Field desalting is necessary due to pipeline requirements.

Challenges: Level instrumentation is integral to single andtwo-stage desalting systems, multiple orifice plate mixers,and the settler tank of a chemical desalter. Interface levelcontrol keeps free water from hitting the desalter electrodesand prevents expensive damage. The interface level shouldbe kept constant, otherwise electrical field changes will dis-turb electrical coalescence.

Two-stage Desalter

Point Level:Series 3 Float-actuated ExternalCage Level Switch;THERMATELModel TD1/TD2Level Switch

Continuous Level:ECLIPSE Model 705Transmitter withEnlarged Coaxial probe;or E3 MODULEVELDisplacer Transmitter

Visual Indication:ATLAS or AURORAMagnetic LevelIndicators can besupplied with switchesor transmitters

5

CRUDE DEGASSING6INSTRUMENTATION

WATER PROCESSING7

INSTRUMENTATION

Application: By removing dissolved gases and hydrogensulfide, crude stabilization and sweetening processesdiminish safety and corrosion problems. Gases areremoved by a stabilizer. Sweetening employs stabilizationor vaporization processes along with a gas or steam-basedstripping agent.

Challenges: Removing dissolved gases by stabilizationrequires level control in the reboiler unit. Sweetening bystage vaporization and trayed stabilization require levelcontrol in a series of staged separators. Sweetening byreboiled trayed stabilization requires additional level controlin a reboiler.

Reboiler

Continuous Level:E3 MODULEVELDisplacer Transmitter; orECLIPSE Model 705Guided Wave RadarTransmitter

Visual Indication:ATLAS or AURORA MLIscan be supplied withswitches or transmitters

Point Level:Series 3 Float-Actuated ExternalCage Level Switch;or TUFFY II Float-actuated Switch

Application: Produced water, wash-down water orcollected rainwater require treatment whether theyrereused for reservoir flooding or simply disposed of. Watercollected from process operations contains hydrocarbonconcentrations too high for safe discharge. Suspendedhydrocarbon droplets in water also hinders well-injection.

Challenges: Treatment equipment is similar to three-phase separators except that water is the main product.Level control is found on skim tanks, precipitators,coalescers, flotation units, and collection tanks andsumps. Interface level measurement is essential for properdraining of clean water and removal of the residual oil.

Water Wash Tank

Point Level:ECHOTEL Model961 UltrasonicGap Switch;Series 3 Float-ActuatedExternal CageLevel Switch

Continuous Level:ECLIPSE Model 705;or Kotron Model 805Smart RF Transmitter;or E3 MODULEVELDisplacer Transmitter

Visual Indication:ATLAS Magnetic LevelIndicator can besupplied with switchesor transmitters

6

PROCESS & STORAGE TANKS8INSTRUMENTATION

VAPOR RECOVERY UNIT FLASH DRUM9

INSTRUMENTATION

Application: Crude oil and water are stored in oil fields.Unlike midstream tank farms at terminals and refineries,field storage consists of smaller vessels associated with oiland water processing. Diesel generator fuel, potable water,and fire water are also stored.

Challenges: Tank level monitoring can be provided withoverflow control and alarm systems or shutdown pumpswhen level falls below the specified low level. Interface con-trols will sense the beginning of an oil/water interface duringtank dewatering and control the water draw-off.

API 2350: New recommended practices regarding tank overfillprotection for above-ground storage tanks that receive Class I(flammable) liquids outline that careful selection and applicationof level controls can effectively protect against tank overfills.

Storage Tanks

Point Level:Model A15 SeriesLevel Switch withoptional Proof-er

Ground Check; orTUFFY II Float-Actuated Switch

Continuous Level:ECLIPSE Model 705 Transmitterwith Flexible Probe; PULSARModel RX5 Non-Contacting,Pulse Burst Radar Transmitters;or E3 MODULEVEL DisplacerLevel Transmitter

Application: If allowed to escape into the atmosphere,hydrocarbon vapors diminish income through loss of hydro-carbon volume and create fire hazards and pollution prob-lems. A Vapor Recovery Unit (VRU) collects vapors fromstorage and loading facilities, reliquefies the vapors andreturns the liquid hydrocarbons back to storage.Methods to recover vapors include absorption, condensa-tion, adsorption and simple cooling.

Challenges: A VRU is a simple, economical process unitthat provides EPA compliance and improves operatingeconomies by capturing up to 95% of fugitive emissions.Critical to the VRU is the flash drum where vapors are reliq-uefied. Liquid level control of the flash drum is essential.

Field VRU

Continuous Level:ECLIPSEModel 705Guided Wave RadarTransmitter;E3 MODULEVELDisplacerTransmitter

Visual Indication:ATLAS or AURORAMagnetic LevelIndicators can besupplied withswitches ortransmitters

Point Level:Series 3 Float-Actuated ExternalCage Level Switch;or TUFFY II Float-actuated Switch; orECHOTEL 961 Switch

Flow Indication:CONTINUOUS:THERMATELModel TA2Mass Flow Meter

7

CORPORATE HEADQUARTERS5300 Belmont Road Downers Grove, Illinois 60515-4499 USA

Phone: 630-969-4000 Fax: 630-969-9489magnetrol.com [email protected]

EUROPEAN HEADQUARTERSHeikensstraat 6 9240 Zele, Belgium

Phone: 052 45.11.11 Fax: 052 45.09.93

BRAZIL: Av. Dr. Mauro Lindemberg Monteiro, 185, Quadrante 16 CEP 06278-010 Osasco So Paulo

CANADA: 145 Jardin Drive, Units 1 & 2 Concord, Ontario L4K 1X7

CHINA: Plant 6, No. 191, Huajin Road Minhang District Shanghai 201109

DEUTSCHLAND: Alte Ziegelei 24 D-51491 Overath

DUBAI: DAFZA Office 5EA 722, P.O. Box 293671 Dubai, United Arab Emirates

INDIA: C-20 Community Centre Janakpuri, New Delhi 110 058

ITALIA: Via Arese, 12 20159 Milano

SINGAPORE: 33 Ubi Avenue 3 #05-10 Vertex Singapore 408868

UNITED KINGDOM: Regent Business Centre Jubilee Road Burgess Hill, West Sussex RH15 9TL

Magnetrol & Magnetrol logotype, Aurora, Echotel, Eclipse, Jupiter, Kotron, Modulevel,

Proof-er, Pulsar, Thermatel, and Tuffy are registered trademarks of Magnetrol International, Incorporated.

Copyright 2011 Magnetrol International, Incorporated. All rights reserved. Printed in the USA.

Bulletin: 41-186.0 Effective: April 2011

AN INDUSTRY GUIDE TO LEVEL MEASUREMENT AND CONTROL FROM MAGNETROL

Other industry and special application brochures from MAGNETROL include:

Chemical Flue Gas Desulfurization Food & Beverage Interface Level Measurement Life Science Mass Flow Measurement Modular Skid Systems Natural Gas Processing Nuclear Power

Petroleum Refining Power Generation Pulp & Paper Mills Renewable Energy Steam Generation Tank Bridle Level Measurement Tank Overfill Prevention Understanding Safety Integrity Level (SIL) Water & Wastewater

PLEASE NOTE: The instruments recommended in these brochures are based on field experience withsimilar applications and are included as a general guide to level and flow control selection. Becauseall applications differ, however, customers should determine suitability for their own purposes.

APPLICATION PAGE

Separation

1. Crude Storage 4

2. Crude Dewatering 4

3. Crude Desalting 5

4. Preflash Drum 5

5. Distillation Column 6

6. Reflux Accumulator 6

7. Column Reboiler 7

8. Solvent Extraction 7

Conversion

9. Catalytic Cracker 8

10. Catalytic Stripper 8

11. Hydrocracking 9

12. Acid Settling Tanks 9

13. Alkylation Tanks 10

14. Catalytic Reformer 10

15. Coking Operations 11

16. Isomerization 11

Treatment

17. Hydrodesulfurization12

18. Chemical Storage 12

Blending

19. Blending Unit 13

20. Finished Products 13

See page 14 for information onrefinery flow controls and leveland flow control applications forrefinery power generation,interface, SIL & wastewatertreatment.

20 Leading

PetroleumRefinery

Level ControlApplications

2

SEPARATION

BLENDINGTREATMENT

An Industry Guide To Level Measurement and Control from Magnetrol

CONVERSION

3

Application: All unrefined crude oil stored intanks has a percentage of water entrained withinit, and while stored in tanks, separation naturallyoccurs with water collecting at the bottom ofthe tank beneath the oil. The two fluids are verydistinct except for a "black water" or "rag" inter-face layer which is an emulsion of mixed oil andwater. To dewater the tank, water is drawn off ofthe bottom of the tank and is then sent off towater treatment.

Challenges: Level controls designed for inter-face detection will sense the beginning of theoil/water interface during dewatering proceduresand provide feedback to a control system whichwill terminate water draw-off when appropriate.

Application: Upon arrival at the refinery termi-nal, crude oil is pumped into above-groundstorage tanks with capacities of thousands tomillions of gallons. Raw crude is stored in float-ing- or fixed-roof tanks field-built to API stan-dards. Tank level measurement by noncontactradar has gained share over mechanical floattype and servo gauges due to its accuracy, lowmaintenance, no moving parts and fast set-up.

Challenges: Tank level is maintained by valveactuation. By triggering an emergency cutoff,level controls prevent overflows and shut downpumps when level falls below low level. Safety-certified controls may be necessary due tocrudes low flash point.

1

2

Crude Tanks

CRUDE DEWATERING

CRUDE STORAGE

Crude Tanks

INSTRUMENTATIO

NIN

STRUMENTATIO

N

Point Level:Model A15Displacer-Actuated LevelSwitch

Continuous Level:Pulsar Model RX5Pulse Burst RadarTransmitter

Continuous Level:Eclipse Model 705Guided Wave RadarTransmitter with 7X7Flexible Twin RodProbe


Continuous Level:ECLIPSE Model 705Guided Wave RadarTransmitter

Continuous Level:E3 Modulevel

Displacer-ActuatedTransmitter or Kotron

Model 805 Smart RFCapacitanceTransmitter

4

PREFLASH DRUM

CRUDE DESALTING

Application: Located in the preheat train of thedistillation column, a preflash drum system sep-arates the vapors generated by preheatingbefore entering the heater or main column. Thisprevents higher heater firing or pressure dropsand reduces vapor loading of the column toavoid flooding.

Challenges: Preflash drums create moderatefoam that can affect measurement accuracy ofliquid levels and decrease distillate productionin the atmospheric column. Too low of a pre-flash drum level will cause pump cavitation ofthe flashed crude. Too high of a level will causeliquid carryover to the distillation column.

Application: Inorganic chlorides, suspendedsolids, and trace metals found in untreated crudemust be removed by chemical or electrostaticdesalting. This reduces the risk of acid corrosion,plugging, fouling and catalyst poisoning indownstream units. Measurement of the oil/waterinterface in the desalter is crucial in separatingthe cleansed crude from contaminants.

Challenges: Coating and build-up on probesmay create interface measurement errors.Instruments susceptible to electrostatic gridinterference may require special filters. Interface-dedicated level transmitters fitted with quick-dis-connect probes provide optimum performancewhile reducing cleaning and maintenance time.

4

3

INSTRUMENTATIO

NIN

STRUMENTATIO

N

Desalting Tanks

Preflash Drum



Continuous Level:E3 MODULEVELDisplacer-ActuatedTransmitter

Point Level:Series 3Float-ActuatedExternal CageLevel Switch

Continuous Level:E3 MODULEVELDisplacer-ActuatedTransmitter; or ECLIPSEModel 705 GuidedWave Radar Transmitter


Magnetic Level Indicatorscan be supplied withswitches or transmitters

5

Application: A heat exchanger removes vaporfrom the upper parts of the fractionator, cools itto a liquid, and pumps it into an accumulator(reflux drum). Reflux pumps then draw liquidfrom the bottom of the accumulator and pumppart of it back (reflux) where it is reintroducedat a lower point in the column. This refluxingprocess improves separation in the column byassuring sufficient downward liquid flow meet-ing the rising vapor.

Challenges: Accurate and reliable level moni-toring and control is necessary for the refluxaccumulator to serve as a distribution point forreflux and distillate, and prevent excessivereflux from returning back to the tower.

Application: Following desalination, crude oilenters the distillation column where fractionaldistillation separates hydrocarbons into sepa-rate streams, cuts or fractions. For optimumoperation of the distillation column, level con-trols must contend with occurances of foaming,bubbling and moderate-to-high temperatures.

Challenges: Sight glasses and displacer sys-tems mounted in external chambers have tradi-tionally provided distillation level measurement.Today, radar retrofitted in these existing cham-bers is gaining popularity due to radars lessdemanding maintenance schedule and ease ofretrofit. High product temperatures necessitatetemperature-tolerant level sensors.

5

6 REFLUX ACCUMULATOR

DISTILLATION COLUMN

Fractional Distillation

INSTRUMENTATIO

NIN

STRUMENTATIO

N

Reflux Accumulator

Continuous Level:E3 MODULEVELDisplacer-ActuatedTransmitter orECLIPSE Model 705Guided Wave RadarTransmitter


Visual Indication:Atlas or AURORA MLIscan be supplied withswitches or transmitters




6

SOLVENT EXTRACTION

COLUMN REBOILER

Application: The heavy fraction remainingfollowing the distillation of crudes is calledpetroleum resids. A variety of solvent-extractionprocesses yield deasphalted oil (DAO) fromthese resids. These oils serve as downstreamfeedstocks for catalytic crackers and hydro-crackers. Depending upon the system configu-ration, level monitoring of the separator, pre-flash, stripper and hot oil phases may includesurge and flash drums, separators and strippers.

Challenges: Level control is critical becauseinterface level control of the separator feeds theflash drum, whose level feeds the stripper, etc.Application extremes include high temperatures,high pressures, and the presence of steam.

Application: A heat exchanger positioned nearthe bottom of the distillation column re-heatsand vaporizes liquid and reintroduces the vaporseveral trays higher. This improves separationby introducing more heat into the column. Foreffective functioning of the reboiling process,level monitoring of the reboiler is required.

Challenges: In some steam reboilers, the levelmust be controlled so that only a percentage oftubes are covered. This allows a control schemeto regulate the heat transfer in the reboiler bycontrolling the percentage of the reboiler tubescovered by liquid. This is a critical control loopas heat transfer into the liquid is a strong func-tion of the percentage of tubes covered.

8

7

INSTRUMENTATIO

NIN

STRUMENTATIO

N

Reboiler


Visual Indication:Atlas or AURORA MLIscan be suppliedwith switches ortransmitters

Flash Tank

Point Level:Series 3 Float-Actuated ExternalCage Level Switchor Tuffy II Float-Actuated Switch


Visual Indication:Atlas or AURORAMLIs can be suppliedwith switches ortransmitters

Point Level:Series 3 Float-Actuated ExternalCage Level Switch

7

Application: Variations in cat cracking includeSelective Component Cracking (SCC) forpolypropylene production, a two-vessel andexternal-reactor design for processing heavyresidue feeds, and a UOP process for convertinggas oils and resid feedstocks. All crackersemploy a steam stripper to remove hydrocar-bons entrained in the spent catalyst.

Challenges: Stripper level control allows suffi-cient residence time for stripping steam to dis-place hydrocarbons for recovery. It also main-tains sufficient pressure to keep air in the regen-erator from reverse flow into the reaction system,thereby causing a hazard. A waste heat recoverysteam drum would also require monitoring.

Application: The Fluid Catalytic Cracking Unit(FCCU) cracks heavy, low-value feedstocks intohigh-value, lighter molecular weight hydrocar-bons which are blended to finished products. Acracker can produce a wide variety of yield pat-terns by operating in either Gasoline, Distillateor LPG modes.

Challenges: Catalytic crackers utilize a reactorand a catalyst regenerator with connecting ris-ers where the reactions take place. Level con-trollers are often positioned on the first stageregenerator and at the top of the reactor. Levelmeasurements involve fluidized solids levels athigh temperatures. Conventional measurementtechniques can be subject to plugging.

9

10

CATALYTIC CRACKER

CATALYTIC STRIPPER

INSTRUMENTATIO

NIN

STRUMENTATIO

N

Regenerator

Stripper

Continuous Level:E3 MODULEVELDisplacer-ActuatedTransmitter

Point Level:Seldom used dueto measurementdifficulties

Visual Indication:Seldom used dueto measurementdifficulties

Continuous Level:E3 MODULEVELDisplacerTransmitter orECLIPSE Model 705Guided Wave RadarTransmitter


Point Level:Series 3 Float-Actuated ExternalCage LevelSwitch or B40Float-ActuatedLevel Switch

8

HYDROCRACKING

ACID SETTLING TANKS

Application: Heavier feedstock difficult toprocess by cat cracking or reforming can beconverted by hydrocracking. By combiningcatalytic cracking and hydrogenation to crackfeedstock in the presence of hydrogen, hydro-cracking produces gasoline and distillate blendingstreams. About a dozen different hydro-crackingprocess schemes are in current use.

Challenges: Level controls for the catalyststripper, separator liquid and flash drum liquidmust contend with severe process conditions tomaintain optimum operation of the hydrocracker.These conditions include elevated temperaturesand pressures, the presence of steam and highpressure hydrogen, and aggressive corrosives.

11

12

INSTRUMENTATIO

NIN

STRUMENTATIO

N

Application: Alkylation is a combining processthat creates alkylate, a premium, high-octaneblending stock. A large acid settler tank withinthe unit allows for separation of theacid/hydrocarbon emulsion created in the reactor.Sight glasses have traditionally measured settlerlevel, but these are susceptible to plugging andrequire diligent flushing at regular intervals.

Challenges: Interface level control of the settleris required. Product/acid cross-contaminationcauses overall efficiency problems and can resultin hazardous conditions. Inaccuratesettler level indication is a frequent cause ofphysical acid carryover in the reactor effluent.Release of acid can cause extreme hazards toboth process and personnel.

Hydrocracking Unit

Settling Tank



Continuous Level:E3 MODULEVELDisplacer-ActuatedTransmitter or ECLIPSEModel 705 GuidedWave Radar Transmitter



Point Level:Series 3 Float-Actuated ExternalCage Level Switchor B40 Float-Actuated LevelSwitch

9

Application: Catalytic reforming upgradeslow-octane naphthas into high-octane gasolineblending components called reformates. Usingheat and pressure with platinum catalysts torearrange hydrocarbon molecules, this processconverts low-octane gasoline fractions intopetrochemical feedstocks and higher octanestocks suitable for finished gasoline blending.

Challenges: A hydrogen-rich gas stream isremoved from the separator for recycling. Liquidproduct monitored for level at the bottom of theseparator is sent to a stabilizer. Where stabilizerfouling has occurred due to the formation ofammonium chloride and iron salts, a monitoredwater wash system should also be included.

Application: Storage and wash vessels in thealkylation unit include those for fresh anddepleted acid and water, an acid analyzer set-tling pot, and a number of wash tanks. Causticwashes neutralize free acid carried over fromthe reaction zone and neutralize alkyl sulfates inthe net effluent. Water washes decomposeremaining esters and remove caustic and saltthat might have carried over from the causticwash.

Challenges: Interface level control in causticand water washes prevents corrosion and foul-ing of the deisobutanizer and other downstreamunits. Levels rising above high set points cancause carryover of caustic or water, while toolow levels can cause hydrocarbon carryunder.

CATALYTIC REFORMER

ALKYLATION TANKS13

14

INSTRUMENTATIO

NIN

STRUMENTATIO

N

Wash Tanks

Continuous Level:E3 MODULEVELDisplacer-Actuated Transmitter orECLIPSE Model 705Guided Wave RadarTransmitter or PULSARRX5 Radar Transmitter

Point Level:Echotel Models910, 961 or 962Ultrasonic LevelSwitches or ModelA15 Displacer-Actuated Switch


Continuous Level:E3 MODULEVEL Displacer-Actuated Transmitter orECLIPSE Model 705 GuidedWave Radar Transmitter orPULSAR Model RX5 PulseBurst Transmitter

Visual Indication:Atlas or AURORAMLIs can besupplied withswitches ortransmitters

Photo of Catalytic Reformer courtesy of CB&I

Point Level:Series 3 Float-Actuated ExternalCage LevelSwitch

10

ISOMERIZATIONApplication: Isomerization in a variety ofprocess configurations alters the arrangementof atoms to convert normal butane into isobu-tane, and normal pentane and hexane into high-octane gasoline components. Isomerization issimilar to catalytic reforming in that the hydro-carbon molecules are rearranged, though iso-merization only converts normal paraffins toisoparaffins.

Challenges: Near the end of the process, reactoreffluent is cooled and separated into the liquidproduct isomerate and a recycle hydrogen-gasstream. Isomerate is caustic-washed and water-washed, acid stripped, and stabilized beforegoing to storage. Stabilizer bottoms and washtanks require level monitoring.

COKING OPERATIONSApplication: Coking is the final means of con-verting the heaviest products of atmosphericand vacuum distillation. Feed is heated andcracked into light gases, gasoline blendstocks,distillates, and gas oil. Level applications fordelayed and continuous (contact or fluid) cokinginclude the fractionator, light gas oil stripper,steam, condensate, blowdown and settlingdrums, and vent gas knockout drums.

Challenges: Process conditions that levelinstrumentation must contend with include hightemperatures, high pressures, foaming, andsteam. An interface level gauge in drums thatare susceptible to foaming will help avoid foam-over and increase coke drum output.

15

16

INSTRUMENTATIO

NIN

STRUMENTATIO

N

Coking Unit

Isomerization Unit




Continuous Level:E3 MODULEVELDisplacer-ActuatedTransmitter; orECLIPSE Model 705Guided Wave RadarTransmitter


Point Level:Series 3 Float-Actuated ExternalCage Level Switchor B40 Float-Actuated LevelSwitch

11

Application: From acids to water treatmentadditives, a wide array of chemicals are storedat a refinery in vessels that range in size fromplastic totes to large steel tanks. Chemicalssuch as sulfuric and hydrochloric acid, sodiumhydroxide, liquid catalysts, blending additivesand water treatment chemicals are essential toa refinerys day-to-day operation.

Challenges: Liquid solution storage and daytanks require stringent level monitoring toensure ongoing chemical processing. The natureof the chemical, the geometry of the holdingvessel, and the presence of mixers or otherhardware will determine the most suitable leveltechnology for the storage or feed application.

Application: Catalytic Hydrotreating treatshydrocarbon liquids in the presence of hydro-gen. This process removes 90% of the sulfur,nitrogen, oxygen, and metals from feedstocks.Hydrotreating can also provide hydrodearomati-zation (HDAr), heavy diesel hydrocracking(HDHDC), dewaxing, and performance enhance-ments of pyrolysis gasoline and diesel.

Challenges: Hydrotreatment will necessitatelevel indication of liquid/gas separators andwater wash tanks. Level devices suited for hightemperatures and pressures are essential inremoving contaminants that can have detrimen-tal effects on equipment, catalysts, and thequality of the finished product.

CHEMICAL STORAGE & FEED

HYDRODESULFURIZATION

Chemical Storage

17

18

INSTRUMENTATIO

NIN

STRUMENTATIO

N

Hydrodesulfurization Unit


Point Level:ECHOTEL Models910, 961 or 962Ultrasonic Switchesor TUFFY II Float-Actuated Switch

Continuous Level:PULSAR Model RX5 PulseBurst Radar or ECLIPSEModel 705 Guided WaveRadar Transmitter with7XF-4 Insulated SingleRod Probe



Point Level:Series 3 Float-Actuated ExternalCage LevelSwitch or B40Float-ActuatedLevel Switch

12

Application: Finished refinery products storedin tanks with capacities that often exceed100,000 gallons are motor gasoline, jet fuel,diesel fuel, fuel oils, and LPG. Marketed prod-ucts also include feedstocks for textiles, tires,pharmaceuticals and plastics.

Challenges: Tank monitoring uses buoyancy,pressure, servo-driven, and radar. Tanks may beprovided with automatic overflow control andalarm systems. Automated tank gauging net-works with proprietary protocols are a vital partof tank farm architecture. Today, thousands oftanks can be linked in a network offeringenhanced data acquisition, fieldcalibration and remote diagnostics.

FINISHED PRODUCT STORAGE

Application: Mixing finished gasoline requireslevel monitoring of blending stocks, in-lineblending, additive storage, dilution systems andinjection systems. Blend stocks are straight-rungasoline, alkylate, reformate, benzene, tolueneand xylene. Additives include octane boosters,metal deactivators, anti-oxidant and knockagents, gum and rust inhibitors, and detergents.

Challenges: Level is normally measured only forinventory control and, in some cases, custodytransfer. The precision of level indication that isrequired varies. If level is used only for internalinventory control, a less accurate measurementcan be used. If level is used for custody trans-fer, highly accurate measurements are required.

Finished Storage

BLENDING OPERATIONS19

20

INSTRUMENTATIO

N

Blending Stocks

Point Level:ECHOTEL Models910, 961 or 962Ultrasonic LevelSwitches

Continuous Level:ECLIPSE Model 705Guided Wave RadarTransmitter or PULSARModel RX5 PulseBurst RadarTransmitter



Continuous Level:PULSAR Model RX5Pulse Burst RadarTransmitter or ECLIPSEModel 705 Guided WaveRadar Transmitter


INSTRUMENTATIO

N

13

Application: The vast piping systems withintodays refineries transport hydrocarbongas/vapor streams, light liquid gas/liquidstreams, heavier liquid streams, water, andsteam throughout the refinery. Certified, reliableand accurate flow measurement is essential fora refinerys safe and efficient operation.

Challenges: Flow alarms and continuous flowcontrols monitor product streams, signal no-flowconditions caused by plugging or valve closure,and provide a defense against pump cavitation.Pumps operating in a reduced or no-flow condi-tion can overheat and rupture the pumps sealand cause a dangerous deviation in processpressure and temperature.

REFINERY FLOW APPLICATIONSINSTRUMENTATION

Water Treatment: In most petroleum refineries, oil comes in contactwith water through steam use and water washing. This water is collectedand sent to treatment to remove oil and other contaminants prior to dis-charge or recycling. Storm water and process water collection systemsalso require water treatment.

Because a thorough discussion of wastewater and water treatment appli-cations is beyond the scope of this brochure, we invite you to log ontowww.magnetrol.com/waterbrochure and download the pdf of theMagnetrol Water and Wastewater Treatment brochure. This 12-pagebrochure describes 14 essential water treatment processesmany ofwhich are applicable to todays refinery operations.

POWER GENERATION & WATER/WASTEWATER

Power Generation: Many petroleum refineries incorporate power generatingplants into their refinery operations. These include power stations with coal-firedboilers and gas-fired co-generation plants.

Because a thorough discussion of power generation applications is beyond thescope of this brochure, we invite you to log ontowww.magnetrol.com/powergenbrochure and download the pdf of theMAGNETROL Power Generation brochure. This 18-page brochure describes20 essential level control applications in power generationmost of which areapplicable to todays refinery operations.

Continuous Flow:For Continuous Air or GasFlow: THERMATEL ModelsTA1 and TA2 ThermalDispersion Mass FlowTransmitters

Flow Alarm:Thermatel Model TD2Thermal DispersionFlow Switch

Pump Protection:THERMATEL Model TD2Thermal DispersionFlow Switch

14

efinery professionals know that great gasoline can

only originate within a great process scheme. And

that especially means process controls that deliver reliable

service in the most demanding applications. Acquiring level

and flow controls of this high calibre is why so many instru-

ment professionals turn to MAGNETROL.

Our buoyancy products were introduced to refinery

service in 1932. Later we were among the first to apply

thermal dispersion, ultrasound, capacitance and other elec-

tronic technologies to refinery challenges. More recently we

pioneered ECLIPSE Guided Wave Radar and PULSAR Pulse

Burst Radar to bring customers the leading-edge in level

transmittersthe kind that balance sophisticated sensing

technology with simplified ease-of-installation and operation.

MAGNETROL also offers a wealth of application engi-

neering know-how and a worldwide service network thats

second to none. And thats the difference between just

buying an instrument and partnering with a world-class

level and flow specialist.

Contact your MAGNETROL sales representative today

to learn how our products can not only help you create

great gasoline, but will actually increase the profitability of

your refinerys operation.

15

Worldwide Level and Flow Solutions

R

SM

Where Great FuelGets Its Start.




Phone: 052 45.11.11 Fax: 052 45.09.93










Magnetrol & Magnetrol logotype, Aurora, Echotel, Eclipse, Modulevel,

Pulsar, Thermatel, and Tuffy are registered trademarks of Magnetrol International, Incorporated.


Bulletin: 41-176.2 Effective: November 2008



Chemical Crude Oil Processing Flue Gas Desulfurization Food & Beverage Interface Level Measurement Life Science Mass Flow Measurement Modular Skid Systems Natural Gas Processing

Nuclear Power Power Generation Pulp & Paper Mills Renewable Energy Steam Generation Tank Bridle Level Measurement Tank Overfill Prevention Understanding Safety Integrity Level (SIL) Water & Wastewater


A Guide to Level Instrumentation for Onshore/Offshore Natural Gas Processing


2APPLICATION PAGE

1. Inlet Separator 3

2. Chemical Injection 4

3. Amine Separation 4

4. Sulfur Treatment 5

5. Gas Dehydration 5

6. NGL Recovery 6

7. Vapor Recovery Unit 6

8. Storage Tanks 7

9. Water Processing 7

10. Compressor Lubrication 8

11. Compressor Scrubber 9

12. Compressor Waste 9

13. Flare Knock-Out Drum 10

Level & FlowApplications forNATURAL GASPROCESSING

Level and flow controlsin these applications arecrucial for both processcontrol and safetyshutdown systems.

GAS StreamLevel Applications

WATER StreamLevel Applications

Separation

Amine Separation

To Pipeline

Compression

Skim Tanksand Vessels

Sumps

Primary Water Treatment

Collection Tanks

Coalescers

8

To disposalTo reservoir

Secondary Treatment

Coalescers

Flotation Units7

8

Acid Gas

Sulfur Unit

Tail Gas Treatment

3

1

2

Incineration

4

5

Chemicals

6

9

Tail Gas

Offgas

Sulfur Treatment

Water

9

Liquid ProcessingNatural Gas processing is typicallyfound in crude oil drilling and process-ing operations. For information on levelapplications for crude oil processing,see our Crude Oil Processingbrochure.

Flow Applications:

Air and gas flow appli-cations are foundthroughout natural gasoperations. For a briefsummary of theseapplications, seepage 10.

Condensate

Level Applications:

Vapor Recovery

To Fractionator

NGL Recoveryand Storage

10

NOTE: The actual nature and numberof steps in the process of creatingpipeline-quality natural gas dependsupon the source and makeup of thewellhead production stream. In somecases, several of the steps shown inthe schematic above may be integratedinto one unit or operation, performed ina different order or at alternative loca-tions, or not required at all.

Gas

Water Treatment

WELLHEAD

Dehydration

11

12

8

13

Good Practices:

Good practicerecommendations formajor level and flowinstrumentation can befound on page 11.

Application: Separators are large drums designed toseparate wellstreams into their individual components.They are commonly designed to separate two-phase(gas/liquid) or three-phase (gas/crude/water) wellstreams.Separators are also classified according to horizontal orvertical configuration (see below), operating pressure, tur-bulent or laminar flow, and test or production separation.

Challenges: Interface level measurement will actuate avalve to adjust vessel level. An emulsion layer along theoil/water interface can contaminate the oil with water orthe water with oil. Foaming along the gas/liquid interface,if entrained, can cause liquid carryover or gas blowby.

Separator

INLET SEPARATORSINSTRUMENTATION

1

Vertical (right): Vertical separators can accommodate large surges of liq-uids. They are well suited for high sediment loadsconical bottoms aresometimes attached for large sediment deposits. Vertical separators arepreferred when wellstreams have large liquid-to-gas ratios. These sepa-rators occupy less floor space than horizontal types and are often foundon offshore platforms where floor space is at a premium.

Horizontal (below): These separators are well-suited for three-phaseseparation because of their large interfacial area between the two liquidphases. Horizontal types are preferred when wellstreams have high gas-to-oil ratios, when wellstream flow is more or less constant, and whenliquid surges are insignificant. These separators also have a muchgreater gas/liquid interface area, which aids in the release of solution gasand in the reduction of foaming.

TWO PRINCIPAL TYPES OF SEPARATORS

NATURAL GAS

WATER

GAS OUT

OIL OUTWATER OUT

OILEMULSION

GAS OUT

OIL OUT

NATURAL GAS

WATER

WATEROUT

OIL

EMULSION

INLET STREAMIN

VERTICALHORIZONTAL

INLET STREAMIN

3

Point Level:Series 3 Float-actuated ExternalCage Level Switch;or Thermatel ModelTD1/TD2 Switch

Continuous Level andInterface Level:Eclipse Model 705;Jupiter MagnetostrictiveLevel Transmitter; orE3 Modulevel DisplacerTransmitter


Magnetic LevelIndicators

Application: Chemical agents employed in natural gasprocessing include drilling fluid additives, methanol injec-tion for freeze protection, glycol injection for hydrate inhi-bition, produced water treatment chemicals, foam andcorrosion inhibitors, de-emulsifiers, desalting chemicalsand drag reduction agents. Chemicals are frequentlyadministered by way of chemical injection skids.

Challenges: Level monitoring controls chemical inventoryand determines when the tanks require filling. The carefulselection and application of level controls to chemical injectionsystems can effectively protect against tanks running out ofchemicals or overfilling.

CHEMICAL INJECTION

Chemical Injection Skid

2INSTRUMENTATION

Application: Pipeline specifications require removal of theharmful acid gases carbon dioxide (CO2) and hydrogensulfide (H2S). H2S is highly toxic and corrosive to carbonsteels. CO2 is also corrosive and reduces the BTU value ofnatural gas. Gas sweetening processes remove these acidgases and make natural gas marketable and suitable forpipeline distribution.

Challenges: Amine treatment removes acid gases throughabsorption and chemical reaction. Each of the four com-mon amines (MEA, DEA, DGA and MDEA) offer distinctadvantages in specific applications. Level control applica-tions include reactors, separators, absorbers, scrubbersand flash tanks.

AMINE SEPARATION SOUR GAS TREATMENT

INSTRUMENTATION

Amine Separation

3

4

Point Level:Echotel Model 961Ultrasonic Switch; orTHERMATEL ModelTD1/TD2 Switch

Continuous Level:ECLIPSE Model 705Guided Wave RadarTransmitter; or JUPITERMagnetostrictive LevelTransmitter

Visual Indication:ATLAS or AURORAMagnetic LevelIndicators

Point Level:ECHOTEL Model 961Ultrasonic Gap Switch;or THERMATEL ModelTD1/TD2 Switch



Application: A sulfur recovery unit converts the hydrogensulfide in the acid gas into elemental sulfur. Of the processesavailable for these conversions, the Claus process is by farthe most well-known for recovering elemental sulfur, whereasthe conventional Contact Process and the WSA Process arethe most used technologies for recovering sulfuric acid. Theresidual gas from the Claus process is commonly called tailgas. Tail gas is subsequently processed in a gas treating unit.

Challenges: The sulfur condenser vessel is equipped with adisengagement section on the outlet end in order to allowfor efficient separation of the liquid sulfur from the processgas. A collection vessel equipped with continuous levelcontrol is used to store and remove the sulfur product fromthe process.

SULFUR RECOVERYINSTRUMENTATION

Sulfur Recovery Unit

4

Application: Natural gas dehydration removes hydrateswhich can grow as crystals and plug lines and retard theflow of gaseous hydrocarbon streams. Dehydration alsoreduces corrosion, eliminates foaming, and prevents prob-lems with catalysts downstream. Compressor stations typi-cally contain some type of liquid separator to dehydrate nat-ural gas prior to compression.

Challenges: The most common dehydration method is theabsorption of water vapor in the liquid desiccant glycol. Thewithdrawal of the water rich glycol from the bottom of theabsorber is facilitated by a level control. High and low levelshut down can be applied to the reboiler, surge tank andflash separator.

GAS DEHYDRATION

INSTRUMENTATION

Gas Dehydration Skid

5

5

Point Level:ECHOTEL Model 961Ultrasonic Switch;or THERMATEL ModelTD1/TD2 Switch



Point Level:Tuffy II Float-actuated Switch;ECHOTEL Model 961Ultrasonic Switch; orTHERMATELTD1/TD2 Switch

Continuous Level:ECLIPSE Model 705Guided Wave RadarTransmitter; or JUPITERMagnetostrictiveTransmitter


NGL RECOVERY & STORAGEApplication: Separating the hydrocarbons and fluids frompure natural gas produces pipeline quality dry natural gas.The two principle techniques for removing Natural GasLiquids (NGLs) are the absorption and the cryogenicexpander method. The absorption method is very similarto that of dehydration except that an absorbing oil is usedinstead of glycol. Once NGLs have been removed fromthe natural gas stream, they must be separated out, orfractionated.

Challenges: Absorption method level control is typicallyfound on flash drums, separation towers and reflux sys-tems. Cryogenic method level control is applied to theseparator and dehydrator.

INSTRUMENTATION

6

VAPOR RECOVERY UNIT FLASH DRUMApplication: A Vapor Recovery Unit (VRU) capturesvaluable volatile organic compounds and other richgas streams that may otherwise be a significant envi-ronmental pollutant. A Vapor Recovery Unit (VRU) col-lects from storage and loading facilities, reliquefies thevapors, and returns the liquid hydrocarbons back tostorage. Methods to recover vapors include absorption,condensation, adsorption and simple cooling.

Challenges: A VRU is a simple, economical processunit that provides EPA compliance and improves oper-ating economies by capturing up to 95% of fugitiveemissions. Critical to the VRU is the flash drum wherevapors are reliquefied. Liquid level control of the flashdrum is essential.

INSTRUMENTATION

Field VRU

7

NGL Recovery

6

Continuous Level:ECLIPSE Model 705Guided Wave RadarTransmitter; or E3MODULEVEL DisplacerTransmitter



Continuous Level:ECLIPSE Model 705Guided Wave RadarTransmitter; or E3MODULEVEL DisplacerTransmitter


Point Level:Series 3 ExternalCage Level Switch;TUFFY II Float-actuat-ed Switch; ECHOTELModel 961 UltrasonicSwitch; or THERMATELTD1/TD2 Switch

WATER PROCESSINGApplication: Produced water, wash-down water or col-lected rainwater require treatment whether theyre re-used for reservoir flooding or simply disposed of. Watercollected from process operations contains hydrocarbonconcentrations too high for safe discharge. Suspendedhydrocarbon droplets in water also hinders well-injection.

Challenges: Treatment equipment is similar to three-phase separators except that water is the main product.Level control is found on skim tanks, precipitators, coa-lescers, flotation units, and collection tanks and sumps.Interface level measurement is essential for proper drain-ing of clean water and removal of the residual oil.

INSTRUMENTATION

Water Wash Tank

Point Level:ECHOTEL Model 940/941Ultrasonic Gap Switch;THERMATEL ModelTD1/TD2 Switch; or Floator Displacer-actuatedSwitch

Continuous Level:ECLIPSE Model705 Transmitter;or E3 MODULEVELDisplacer Transmitter

STORAGE TANKSApplication: Natural gas, oil, liquid fuel, treatmentchemicals, extracted condensate from separators andwater are stored in gas fields. Unlike midstream tankfarms at terminals and refineries, field storage consistsof smaller vessels. Diesel generator fuel, potable water,and fire water are also stored in tanks.

Challenges: Tank level monitoring can be providedwith overflow control and alarm systems or shutdownpumps when level falls below the specified low level.Interface controls will sense the beginning of anoil/water interface during tank dewatering and controlthe water draw-off.

INSTRUMENTATION

Storage Tanks

Point Level:Model A15 SeriesLevel Switch withoptional Proofer; orECHOTEL Model 961Ultrasonic GapSwitch

Continuous Level:ECLIPSE Model 705Transmitter; Pulsar ModelRX5 Radar Transmitter; orJUPITER MagnetostrictiveTransmitter

8

9



7

NATURAL GAS COMPRESSION

Above, a gas compression skid designed for field use. The configuration of acompressor is determined by its compression capacity, by whether it is a tur-bine or reciprocating type, by its power source, and by the environmental orsound attenuation requirements that may be required.

From natural gas extraction to pipeline tranmission, compressorsare an essential technology employed throughout production anddistribution chains to increase the pressure of natural gas byreducing its volume. At the wellhead, compression allows a low-pressure well to produce higher volumes of natural gasin someinstances, well production may be entirely dependent upon gascompression. In natural gas processing plants, intermediate andend product gases are compressed tofacilitate gathering and processingoperations. In pipeline transport ofpurified natural gas, compressionstations ensure the movement ofgas from the production site to theconsumer. Compressors may alsobe used in association with aboveground or underground natural gasstorage facilities. Three typical leveland flow applications related to gascompression follow below.

COMPRESSOR LUBRICATION TANKApplication: Lubrication systems protect compressor com-ponents from increased amounts of wear and deposit forma-tion and help the equipment run cooler and more efficiently. Awide range of engine lubricants formulated with different baseoils are available. Lubricants vary by ISO grade, viscosity,flash point, and formulation. Lubricating fluids are typicallystored in integral stainless steel and carbon steel tanks and inremote bulk storage tanks that are monitored for level.

Challenges: Level monitoring of lubricant reservoirs willensure the proper functioning of compressors. Temperatureshifts in integral reservoirs affect media density that willexclude some level technologies, such as pressure trans-mitters. Because ISO cleanliness levels increase lubechange frequency, controls should be easy to remove.

INSTRUMENTATION

Compressor Unit

10

8

Point Level:ECHOTEL Model 961Ultrasonic GapSwitch; THERMATELModel TD1/TD2Switch; or TUFFY IIFloat-actuatedSwitch



COMPRESSOR SCRUBBER

COMPRESSOR WASTE LIQUID

Application: Natural gas can travel through thousands ofmiles of pipeline. Compressors placed at key intervals keepthe natural gas moving evenly and reliably. A typical com-pressor station consists of an inlet scrubber to collect liq-uids and slugs that may have formed in the gas pipeline.The scrubber consists of a primary section where liquidsand solid parts are separated from the gas stream and asecondary section where oil mist is removed.

Challenges: The liquids collected from the suction scrubberare typically routed by way of scrubber level control valves toa low pressure (LP) tank. The vapors produced from theflashing liquids are vented to the atmosphere or to a flare.The low pressure condensate is periodically trucked out.Scrubbers are often equipped with high and low level alarms.

INSTRUMENTATION

11

Application: Compression station scrubbers and filters thatcapture liquid waste and unwanted particles route waste liq-uids to a storage tank. Wastes can be water condensates orheavier hydrocarbons from the natural gas. The wastes arecollected in one or several tanks depending on the size ofthe remote station. As a waste tank fills, tank trucks aretypically scheduled for tank emptying operations. As thesewastes are hazardous materials, the waste holding tanks areclassified as Class 1, Div. 1 areas.

Challenges: Measurements for both total level and interfacelevels between the condensed hydrocarbons and condensedwater are typically made. Tank level monitoring can be provid-ed with overflow control and alarm systems or shutdownpumps when level falls below the specified low level.

INSTRUMENTATION

Underground Waste Tank

12

Scrubbers

Point Level:ECHOTEL Model 961Ultrasonic GapSwitch



9




FLARE KNOCK-OUT DRUMApplication: Liquid in the vent stream can extinguish theflame or cause irregular combustion and smoking. In addi-tion, flaring liquids can generate a spray of burning chemi-calsa rain of firethat create a severe safety hazard. Aknockout drum collects these liquids prior to entering theflare system. A level gauge and drain connections are builtinto the knockout drum.

Challenges: When a large liquid storage vessel is requiredand the vapor flow is high, a horizontal drum is usuallymore economical. Vertical separators are used when thereis small liquid load, limited plot space, or where ease oflevel control is desired. Knockout drums are equipped withinstrumentation to monitor liquid level with pump out ordrain facilities. High and low level alarms are frequentlyinstalled in knockout drums.

INSTRUMENTATION

Knockout Drum

13

AIR and GAS FLOW MONITORINGApplication: From the wellhead to the compression sta-tion, monitoring the flow of natural gas is essential. Otherflow monitoring applications found in natural gas settingsmay include mass air and compressed air flow, processand waste gas flow (often required for reporting environ-mental emissions), and pump protection afforded by thesensing of reduced or no-flow conditions.

Challenges: Significant flow variables include pipe diame-ters, wide flow ranges, varying velocities, and low flowsensitivity. Flow meters ensure efficient operation at ratedSCUM output and also detect leaks. A flow meter with atotalizer provides an accurate measurement of air or gasconsumption. A flow switch along a pumps discharge pip-ing will actuate an alarm and shut down the pump whenliquid flow drops below the minimum flow rate.

INSTRUMENTATION

Flow Alarm:THERMATEL ModelTD1/TD2 ThermalDispersion FlowSwitch

Continuous Flow:THERMATEL Model TA2Thermal Dispersion MassFlow Meter

Pump Protection:THERMATEL Model TD1/TD2Thermal Dispersion Flow Switch

10

Point Level:ECHOTEL Model961 UltrasonicGap Switch; orExternal CageFloat Switch

Continuous Level:ECLIPSE Model 705Guided Wave RadarTransmitter; or E3MODULEVELDisplacer Transmitter


35 diameters

5diameters

5diameters

5diameters

5diameters

5diameters

15 diameters

20 diameters

15 diameters

15 diameters

FLOW

FLOW

FLOW

FLOW

FLOW

FLOW

5diameters

50 diameters

Probe Installations

90-Degree Elbow

Two 90-Degree Elbows in Plane

Two 90-Degree Elbows out of Plane

Reduction

Expansion

Control Valve - It is recommended that controlvalves be installed downstream of the flow meter.

Flow Meter Straight Pipe Installation, Upstream and Downstream

The figure below indicates the minimum recommended straight-run distancesrequired to obtain the desired fully developed flow profile for a THERMATEL Model TA2Mass Flow Meter. If these straight-run distances are not available, the overall accuracyof the flow measurement will be affected; however, the repeatability of the measurementwill be maintained. Calibration requires the TA2 sensor to be positioned in a test section;the test section should have a sufficient upstream and downstream straight run toensure the formation of a fully developed flow profile. Calibration should be performedusing the same gas which the unit is calibrated for.

Good Practices for Leading Level and Flow Instrumentation

Guided Wave Radar Probe Buildup

Natural gas, condensate and crude processing applications have some special requirements thatare not evident from Instrument Data Sheets. Experience has lead to some simple but effectiverecommendations to address these field issues not contained in Data Sheets. Natural gas, conden-sate and crude processing applications can experience paraffin, asphaltenes, grit and grimebuildup. The degree of buildup varies widely. Even in applications where it isnt prevalent, over timeit can happen during cold weather periods or when bringing units up or down due to temperature,pressure and process material fluctuations. Like distillation columns, chambers/cages/bridles mayrequire cleaning from time to time. Even direct insertion GWR probes can at times experiencebuildup. Below are some good practices that can minimize build up and reduce maintenance time.

Use Enlarged Coax GWR Probes with more clearance for buildup to occur. Consider using the Model 7xG Chamber Probe whenever possible. The 7xG provides thesensitivity and performance of a coaxial probe with the viscosity immunity of a single rod.

Insulate the probe necks of Overfill Probes to reduce any cooling at the top of the probeinside the vessel, chamber, cage or bridle.

Chambers should be insulated even in warm weather locations. The temperaturedifferential between a warm/hot vessel (like a separator) and uninsulated chamber/cagescan be significant resulting in paraffin deposition and/or viscosity increases.

Insulate chamber flanges to reduce any cooling at the top of the probe Use probes with integral flushing connection to simplify flushing/dissolving puffins or grit.Flushing connections are an option available on all Magnetrol coaxial GWR probes.

Use probes that have low end dielectric specifications (a 1.4 rating) in the application,especially for condensates.

7XDHTHPCoaxial

7XGCaged

Single Rod

7XTInterfaceCoaxial

Of relevance to:

Gas Production Gas Processing Facilities Platforms Crude Production

11




Phone: 052 45.11.11 Fax: 052 45.09.93










Magnetrol & Magnetrol logotype, Atlas, Aurora, Echotel, Eclipse, Jupiter, Modulevel,Pulsar, Thermatel and Tuffy are registered trademarks of Magnetrol International, Incorporated.


Bulletin: 41-187.0 Effective: July 2011



Chemical Crude Oil Processing Flue Gas Desulfurization Food & Beverage Interface Level Measurement Life Science Mass Flow Measurement Modular Skid Systems Nuclear Power

Petroleum Refining Power Generation Pulp & Paper Mills Renewable Energy Steam Generation Tank Bridle Level Measurement Tank Overfill Prevention Understanding Safety Integrity Level (SIL) Water & Wastewater


S p e c i a l A p p l i c at i o n S e r i e s

THERMATEL MASS FLOW MEASUREMENT

Mass Flow Measurement

Thermal flow meters measure flow rate in units ofmass flow (SCFM or NM3/hr) rather than flow at oper-ating conditions. Because temperature and pressurevariations will influence the gas density, mass flowmeasurement provides optimum measurement accuracydespite temperature and pressure variations.

In addition to greater measurement accuracy, massflow is also measured to accommodate an industrysmeasurement standards. Chemicals react on the basisof mass relationships of ingredients. Combustion isbased upon the mass flow rate of the air and fuel. Inaddition, a facilitys gas consumption is based uponmass flow.

Thermatel

Technology

Operating on thebasis of heat transfer,THERMTATEL TA2transmitters measuremass flow bydetecting heat dissipation from a heated surface.Their sensor probes contain two mass balanced ele-ments with precision matched RTDs. The referenceRTD measures the process temperature (up to +400 F,+200 C) while the second RTD measures the temper-

ature of the heated sensor.A brief discussion of the TA2

technology follows on page 4.For a thorough discussionof thermal dispersiontechnology, download our32-page Thermatel

Measurement Handbook atwww.MAGNETROL.com.

Thermatel Benefits

THERMATEL flow meters offer distinct advantagesover many traditional gas flow measuring methods*:

Direct mass flow measurement does not requirepressure or temperature input for density correc-tion as do many gas flow technologies, such asdifferential pressure.

Offers excellent low flow sensitivity: mass veloci-ties of 10 ft/min (0.05 m/s) to 50,000 ft/min(250 m/s) (gas dependent).

Measures low velocities as well as high flow ratesfor a turndown rate of 100:1 or more.

THERMATEL probes create negligible pipe blockageresulting in very low pressure drops.

THERMATEL measurement functions are accom-plished without moving partsresulting in little orno maintenance and fewer on-line problems.

THERMATEL transmitters have been engineeredfor easy installation and fast set-up while providingrugged, accurate and reliable service.

Calibrated for your application, each instrument isready for immediate field installation and operation.

Installed cost of THERMATEL is very competitivewith other gas mass flow measurement technologies.

FM, FMc, ATEX approvals for combustible gases.

Available as insertion or Inline styles.

Flow body designs for pipe sizes as small as12 inch

*These conditions will compromise THERMATEL performance:

(1) a continuous presence of condensed moisture;

(2) an excessive probe buildup; (3) an attempt to measure

media for which the instrument was not calibrated.

Introducing Thermatel

Magnetrol TA2 thermal mass flow transmitters measure mass flow by detecting heat dissipation from a heated surface.

2

3Supply Voltage: 100-264 VAC, 50-60 Hz11.6-30 VDC

Flow Range: 10-50,000 SFPM (0.05-250 Nm/s)(gas dependent)

Flow Accuracy: 1% of reading plus 0.5%of calibration range

Temperature Accuracy: 2 F (1 C)

Repeatability: 0.5% of reading

Sensor Range: -50 to +400 F (-45 to +200 C)Rated to 1,500 psig (103 bar)

Turn Down: 100:1 (application dependent)

TA2 S P E C I F I C A T I O N S

TA2 I N D E P T H

Integral or Remote:All electronics are housed ina compact, explosion-proofenclosure mounted on theprobe or at a remote location.

Display: Optional two-line,16 digits/line, alphanumericbacklit display module withfour-button keypad for easyconfiguration. Displays flowrate, temperature, totalized flow,and diagnostic messages.

TA2 Electronics Features: Unit accepts both 11.5 to 30 VDC and 100264VAC input power Rotatable housing for viewing display at virtuallyany angle Active and passive 4-20 mA output of flow Second mA output for temperature or secondflow range Pulse output available for external totalizer or PLC HART and PACTware communications Real time temperature compensation Automatic pipe blockage adjustment Very low heat input Unit delivered factory calibrated and configuredsimplifies startup Flow profile compensation Easy. Intuitive software configuration Software totalizer displays the totalized flowusage in the users choice of engineering units. Both resettable and non-resettable totalizer Complete diagnostics monitor condition ofprobe, circuit, wiring and even RTD sensor drift

Insertion (left) or In-Line style (above)

Process Connections: Selection ofprocess connections includes threads,welded flange construction, and usewith a compression fitting.

Probe: All-welded 316 stainless steel;Hastelloy C-276 optional. Process tempera-tures to +400 F (+200 C); Pressure rating to1,500 psig (103 bar); ratings are dependentupon process connections.

Convenience: Probe is field-replaceable; Optional hot tapRetractable Probe Assembly(RPA) allows for probeinstallation or removalwithout a process shut-down. At right, standardand high pressure RPAs.

Protection: Sensor isprotected within a durableenclosure to prevent damageif the probe is inserted toofar into a pipe.

4Principle of OperationTA2 thermal mass flow transmitter technology for measuring mass flow.

The TA2 uses the proven Constant TemperatureDifference Technology for mass flow measurement.There are two elements in the sensor as shown onpage 2. The RTD in the reference pin measures theprocess temperature of the gas where the sensor islocated; a variable amount of power is applied to theheater in the second pin to maintain a specifiedtemperature difference. The amount of the temperaturedifference is set during the calibration to optimize theperformance for the particular application.

At low mass flow rates there is little heat transferand the amount of power required to maintain thedesired temperature difference is low. However, as themass flow rate increases, the power requirementsincrease. Changes in heat transfer are greatest at lowvelocities which provide excellent low flow sensitivity.As the mass flow increases the power increases in anon-linear manner as shown in the chart below. Thecurve continues permitting flow measurements at highvelocities; this provides very high turndown capabilities.

The units are factory calibrated to establish thisrelationship between heat transfer and mass flow.Calibration is performed by placing the TA2 in a flowbench and flowing a known amount of gas past thesensor. The signal is measured at each flow rate.A minimum of 10 data points are taken over the operatingrange of the instrument. Once calibrated this is apermanent calibration unless something happens tothe sensor. The TA2 provides a simple method whichpermits the user to verify calibration in the field.

The TA2 is designed with advance digital electronicswhich produce very low amounts of heat input to thesensor. Testing by FM has demonstrated a maximum ofa 4 C (7.2 F) temperature rise of the heated elementwhich is much lower than other designs. This permitsthe TA2 to measure much higher velocities than otherdesigns without running out of power.

One of the advantages of the Constant TemperatureDifference Technology is the response time. There issome thermal mass which needs to heat up or cooldown with changes in flow. The TA2 incorporates anadvance PID control circuit which immediately detectschanges in temperature difference to provide very rapidresponse in the flow measurement. Once at constantflowing conditions, the signal remains extremely stable.

Mass Flow Rate

Po

wer

Flow Calibration Curve

Measuring Mass Flow in Large Pipes and Ducts.

ABOVE: Two, custom-engineeredmulti-point arrays. BELOW: Fourstandard TA2 flow meters.

he larger the diameter of apipe, stack or duct, the

greater the likelihood of significantflow velocity profile distortions. Inthese highly skewed flow condi-tions, a single point flow meterwont do the job. So, whats thebest measurement solution?

A frequent choice for greatermeasurement accuracy is themulti-point sensor array. Here,two or more flow sensors areplaced along an extended-lengthinsertion element. With more sen-sor points across the interiorexpanse of the duct, the morerepresentative will be the flowmeasurement. And, if you installtwo of these arrays in crisscross

fashion inside the duct (as dia-gramed at top right), you have asensor array that will provide verygood results. The price you payfor this set-up, however, is cost;for the multi-point array is engi-neering-intensive at the front end,and maintenance-intensive downthe line.

Option #2 is to insert four TA2s(or more, as needed) from oppo-site sides of a duct (bottom right)and average their output signals.This approach uses standardTHERMTATEL flow meters foraccurate and reliable mass flowmeasurement at a lower installedcost, and with less maintenanceheadaches in the future.

T

Mass Flow of AirApplications: The flow of air (78% nitrogen, 21%

oxygen and traces of eight other gases) is monitored in

nearly all industrial settings, including applications for

processing; air/gas mixing; cooling; blowing & drying;

combustion; aeration; ventilation; filtration; ingredient

mixing; air sampling, and many others. Significant air-

flow variables include pipe diameters, wide flow ranges,

varying velocities and low flow sensitivity. Large-duct

flow applications for THERMATEL include combustion

air flow used in determining fuel-to-air mixtures for

industrial boilers, heaters, furnaces and kilns.

TA2 Air Flow Applications:

Aeration Flows Wastewater Treatment Combustion Air Boilers, Kilns, Heaters Test Air Flow Pump and Equipment Mfgrs. Air Flow Rate Metals Processing and Recovery Spray Drying Food, Bio-Pharm, Chemical Remediation Agricultural, Environmental Heat Treating Manufacturing, Metals Drying Air Flow Pulp and Paper Reheat Air Flow PowerGen Leak Detection All Industries

The combustion efficiency of burners, furnaces anddryers is enhanced by obtaining repeatable flow meas-urement of the inlet combustion air. Ducts can vary fromsix-inches in diameter to many square feet. Too little airand combustion is incomplete; too much air and com-bustion efficiency is greatly reduced.

Application Insights

5

Compressed Air FlowApplications: Air that is compressed and contained

at a pressure greater than atmosphere has become

industrys universal power source. Seventy percent of

all manufacturers operate compressed air (CA).

Process operations dependent upon CA include pneu-

matic tools; materials handling; painting; oxidation;

fractionation; cryogenics; refrigeration; dehydration;

filtration and aeration. Flow meters help ensure effi-

cient operation at rated SCFM output and are also

used to detect leaks. A Flow Meter with a Totalizer

provides an accurate measurement of CA consumption.

TA2 Compressed Air Flow Applications:

Automation & Process Systems All Industries Pneumatic tools, Painting All Industries Materials Handling Systems All Industries Filling, Capping, Packaging Bottling, Packaging PET, PE Bottle Blowing Plastic Containers Labs, Pill Coating Pharmaceuticals Soil Remediation Environmental Industry Drilling, Pipelines Oil and Natural Gas Pressurizing Gas Lines Natural Gas Food & Drug Processing Foods, Pharmaceuticals

Nitrogen Gas FlowApplications: Nitrogen gas (N2) is the most widely

used commercial gas. Colorless, odorless, tasteless,

and nonflammable, its inertness makes it an ideal

blanketing gas to protect flammable or explosive

solids and liquids from contact with air. Keeping

chemicals, pharmaceuticals and foods within a nitro-

gen atmosphere keeps them protected from oxygen

and moisture degradation. Oil, gas and petrochemical

industries purge tanks and pipes with nitrogen to

replace hazardous or undesirable atmospheres. In

refinery maintenance, nitrogen quickly cools catalyst

temperatures to vastly reduce shutdown time.

TA2 Nitrogen Gas Flow Applications:

Tank Blanketing Chemicals, Foods, HydrocarbonsBio-Pharm, Semi-Conductor

Gas Purging Natural Gas, Refinery Industries Pressure Transfer Storage Vessels, All Industries Cooling, Freezing Refineries, Food Processing Forming Control Metal Casting Heat Treatment Shield Gas for Steel and Iron Pill & Tablet coating Pharmaceutical, Nutritional Inerting of LNG Tankers, Transport Vessels Drilling, Processing Oil and Natural Gas Industries

Nitrogen flow in a two-inch line at a chemical plant.Point-of-use consumption of compressed air and gaseswill permit the user to obtain improved usage rate infor-mation for more efficient operations. Some centralizedfacilities bill the individual plants for gas usage.

This Glycol Regeneration Skid serving a natural gasfield in Holland features three TA2stwo measuring airflow to an incinerator and one measuring natural gas.

Natural gas is one of the major energy sources forfueling large central power stations as well as smallerindustrial furnaces and boilers. Flow rate measure-ment and totalization of flow usage are vital to effi-cient operations.

6

Thermatel: Precisely Calibrated To Your Gas Flow Requirements.

very gas has distinct thermal properties thataffect the convective heat transfer of the

THERMATEL sensor. It is for this reason that eachflow meter is calibrated inthe Magnetrol CalibrationLab to our customers spe-cific requirements. Theinstrument is performancetested under conditions ofgas composition, flowrates, velocities, and tem-peratures. Once installed,the unit goes directly intoservice without any needfor field set-up, calibration, or adjustment.

Our customer has total control over field con-figuration of the TA2. By using a simplified proce-dure, they can configure the instrument in orderto change pipe or duct size, the range and span

of the 4-20 mA signal, the units of measurement,or installation factors.

Some competitors flow meters require theircalibration to include a speci-fied cable length, and any sub-sequent cable changes willaffect the units accuracy.The TA2 cable length is inde-pendent of their calibration.This allows our customers toprovide their own cable, orchange its length in the field.

The TA2 probe and circuitboards are also field replace-

able. New calibration factors can beentered into the instrument by usingthe TA2 keypad or with a HART

remote communicator.

TA2

The Magnetrol NIST TraceableCalibration Facility

E

Natural Gas FlowApplications: Natural gas is a mixture of hydrocar-

bon gases, primarily (70-90%) methane (CH4). In its

pure form it is colorless, odorless and combustible.

The cleanest burning fossil fuel, natural gas trails

electricity as the second most used energy source in

industry. Industrial demand accounts for 40 percent

of total natural gas demand, the highest of any sec-

tor. With a multitude of industrial uses, natural gas is

consumed primarily in pulp and paper; metals manu-

facture; power generation; petroleum refining; stone,

clay and glass manufacture; chemicals production;

plastic resin production; and food processing.

TA2 Natural Gas Flow Applications:

Extraction, Production Natural Gas Industry Waste Treatment, Incineration All Industry Sectors Co-Firing Technology Power Generation Base Ingredients, Feedstocks Plastics, Chemicals, Bio-Pharm Preheating, IR heating Iron and Steel, Powder Coating Processing Food, Chemicals, Refining, Paper Manufacturing Stone, Clay and Glass Primary and Backup Fuels Industrial Boilers, Furnaces Gas Desiccant Systems Plastics, Bio-Pharm, Confections Gas Absorption Systems Heating & Cooling of H2O

Natural gas flow at a gas production plant ismonitored to provide flow measurement from eachindividual well. The main custody transfer meter ispositioned downstream from where the flow fromindividual lines is combined.

Application Insights

7

Hydrogen Gas FlowApplications: Hydrogen (H2), the lightest of gases, is

colorless, odorless, tasteless, flammable and nontoxic

(at atmosphere). It has the highest combustion energy

release per unit of weight of any commonly occurring

material. Hydrogens industrial applications include

chemical processing; metal production; petroleum

refining; electronics; power; pharmaceuticals and

foods. With the development of a viable fuel cell tech-

nology, new application opportunities in the automo-

tive sector will no doubt surface. Consideration must

be given to Hydrogens volatility and its greater cooling

effect on the sensor compared to other gases.

TA2 Hydrogen Gas Flow Applications:

Treating, Welding, Annealing Steel, Stainless Steel, Copper Hydrodesulfurization Oil Refineries Catalytic Cracking Oil Refineries Vitamin Manufacturing Pharmaceuticals, Supplements Oxidation Preventative Glass Manufacturing Hydrogenation of Fatty Acids Food and Dairy Carrier Gas Integrated Circuits Generator Coolant Power Generation Rocket Fuel, Fuel Cells Aerospace, Automotive Making NH3, CH3OH, H2O2 Chemicals, Polymers, Solvents

Argon Gas FlowApplications: Composing slightly less than 1% of the

air, Argon (Ar) is a colorless, odorless, tasteless, non-

corrosive, nonflammable, and nontoxic gas. It is the

most abundant of the rare gases, those with an

extremely weak tendency to chemically interact with

other materials. Argon is commercially valued in multi-

industry applications for its near total inertness and low

cost. Argon is utilized to produce specialty products;

protect and maintain product quality; and lower operat-

ing costs in steelmaking. It is essential in metal fabrica-

tion; light bulbs; the production of electronic equipment;

and in thermal glass and plastics manufacture.

TA2 Argon Gas Flow Applications:

Degasification Aluminum, Titanium, Stainless Steel Heat Transfer Electronics, Semiconductors Bulb Media Fluorescent, Incandescent Lighting Thermal Media Thermopane Window Manufacturing Argon Lasers DNA Sequencing, Electronics, Printing Arc, Tig, Mig Welding Manufacturing, Metal Fabrication Filler Gas Silicone and Germanium Manufacturing Gas-plasma Treating Plastics, Painting and Coating Spectrometry Anodizing, Plating, Powder Coating Cryoablation Medical technology

Retractable Probe Assemblies (RPAs) permit installa-tion of the instrument in applications which must remainin continuous operation. RPA designs with pressure rat-ings up to 720 psi are available.

Hydrogen gas has many industrial applications. Usinga catalyst and large quantities of hydrogen, hydrotreat-ment (above) removes 90% of the sulfur, oxygen, nitrogenand metals from gasoline refinery feedstocks.

The flow of large ducts and stacks, as in this powergeneration boiler, can be measured using multiple stan-dard TA2 units to obtain an averaging of the flow rate.This approach is more economical and easier to maintainthan custom-designed, multiple-point array systems.

8

Oxygen Gas FlowApplications: Oxygen (O2) is the second-largest vol-

ume industrial gas. Because it forms compounds with

virtually all chemical elements it is most often bound

with other elements in silicates, oxides, and water

compounds. Oxygen is highly oxidizing and reacts vig-

orously with combustible materials generating heat in

the reaction process. Ozone (O3) is an allotropic form

of oxygen that is more reactive. Oxygen finds numer-

ous uses in steelmaking and metals refining; chemicals

and pharmaceuticals; petroleum processing; glass and

ceramic manufacture; pulp and paper manufacture;

and in municipal and industrial effluent treatment.

TA2 Oxygen Gas Flow Applications:

Furnace Combustion Steel Making, Haz Mat Industry Metal Processing Copper, Lead, Zinc Manufacturing Glass Smelters Glass Manufacturing Raw Material for Oxidation Chemical Industry Coal Gasification Chemical Feedstock Production Catalyst Regeneration Oil Refineries Oxy-fuel Furnaces Glass Manufacturing, Pulp & Paper Pulp Bleaching Agent Pulp & Paper Biological Treatment Municipal Wastewater Treatment Water Oxygenators Aqua Culture, Water Treatment

The largest industrial user of gaseous oxygen isthe ste

magnetrol o&g

Documents

water processing

crude desalting

chemical agents

processing facility

crude degassing

continuous gas flow

water treatment chemicals

processing timeby