Birthday and Life Expectancy Calculator

Hi, 

Do you plan to surprise your friends, family or spouse with unique birthday facebook, twitter, whatsapp,or bb message.

Ever wonder how many days you've been alive?

Birthday and Life Expectancy Calculator calculates how long you or your your friends, family, spouse have been alive in years, months, weeks, days, hours, minutes and seconds.

you can share the results on facebook, twitter, whatsapp,bb, .etc

LNG Process

LNG process uses exactly the same principle of our refrigerator or Air conditioning
It has the same basic component and refrigeration cycle.
- Compressors
- Condensers
- Expansion Valves
- Evaporators

 

LNG Plant liquefy ga to minus 160 degC. with 80000 hp compressors and mixture of propane, ethane, methane and nitrogen as an input.

Natural Gas Contaminants

below are list of natural gas contaminants:
- Acid Gases (CO2)

- Acid Gases (Sulphur Compound)
- Mercury (Hg)
- Water (H20)
- Heavy Hydrocarbons (C5+)

Personal savings calculator

Hi,

Currently we are developing mobile personal savings calculator. which can help you  to calculate your personal savings goal target.

Example:

Paul wants to become an millionaire within 10 years period. His current annual salary is $90.000. with $36.000 expense annually. He expect to get an 10 % salary increase a year.  After calculation, he will have $ 540.005 on his savings.

safety design

Pada 23 Maret .2005 jam 1:20 siang, di BP Texas City refinery terjadi ledakan dan api yang mengakibatkan 15 orang meninggal dunia dan menciderai 180 orang dengan kerugian material melebihi $1.5 billion. Insiden terjadi ketika start-up isomerization unit, raffinate splitter tower meluap. Pressure relief device terbuka yang menyebabkan  flammable fluid keluar dari blowdown stack yang tidak dilengkapi dengan flare. Keluarnya fluid ini menyebabkan ledakan dan api. Fatality terjadi di kantor yang dekat lokasinya. 43.000 orang penduduk diperintahkan tetap didalam ruangan dan ledakan mengakibatkan rumah-rumah dalam radius ¾ mile dari refiney rusak.

Differential Pressure Level Transmitter Defect

Every liquid in storage tank will have hydrostatic pressure equal to the height of the liquid. With an assumption that the liquid has constant density. The DP level transmitter indication is a measure of the head pressure in the level of the tank whose level is to be detected. Head Pressure, DP, is calculated as DP = (Height).(Specific Gravity).

For example, let's say  50% level is displayed in the control room, the specified SG = 0.8. The DP transmitter is actually measure a differential pressure (50%)*(0.8) = 40 units of the differential pressure.

Gas Processing Unit Summary

Produced wellhead gas is wet, saturated with heavy hydrocarbons and contained with salt and sand.
Gas Conditioning Unit varies from a small station that handle 10 million SCFD to a big station that process 500 Million SCFD.

Wells scattered throughout the remote regions, and then carried by export line to the processing unit. Liquid are separated from gas. The liquids consist of salt water and condensate. The condensate is collected to oil refinery, where the condensate is blended into gasoline. The water is removed and then injected back into the ground in disposal wells.

The Logic Behind The Magic." Flash Gas Compression"

The condensate separated in the Liquid separator is stabilize by the condensate stabilization unit.
To recover the flash gas from the condensate stabilizer column and overhead of liquid separator, Flash gas compressor is installed for the compressing and recycling the gas to inlet of slug catcher.

Flash gas compressor is horizontal multistage cylinder balanced opposed type reciprocating compressor. These compressors are driven by 160 kW induction motor through a direct rigid coupling.

First, the gas flows to Flash Gas Compressor Scrubber to be scrubbed and condense any liquid from the gas stream.

The gas is then compressed by 1st stage flash gas compressor then the discharge gas cooled down from 116 deg C to 80 degC by 1st stage flash gas after cooler. After that condensed liquid is separated in the 2snd stage flash gas compressor suction scrubber prior compression by 2nd stage flash gas compressor to 48.5 barg. The compressed flash gas is cooled down to 90 degC by 2nd stage flash gas after cooler prior delivering to the slug catcher

The Logic Behind The Magic." Gas Dew Point Control and Metering 3".

Metering

The purpose of the flow metering system is to measure the gas flow for commercial purposes.
Sales gas metering package includes the dollowing:
- Flow Metering system
- Gas Chromatograph
- Miscellaneous component, like isolation valve, tube JB, etc.

One of the options is utilizing senior orifice meter. The flow meter is designed and constructed in accordance for AGA Report No 2. To compesate the flow readings, Pressure and Temperature transmitters are provided on each stream.

The Logic Behind The Magic." Gas Dew Point Control and Metering 3".

Gas Dew Point Control .

The Logic Behind The Magic." Gas Dew Point Control and Metering".

Dry gas from TEG overhead KO drum flows to Gas/Gas Exchanger where it is cooled by Low Temperature Separator overhead stream. The Gas/Gas Exchanger is a special Printed Circuit Heat Exchanger design. The exchanger is protected by strainers in order to avoid oversized particles entering Sales Gas Metering Skid.

The Logic Behind The Magic." Glycol Dehydration System 10"

Glycol Make Up System and Drain Vessel Control

The Logic Behind The Magic." Glycol Dehydration System 9"

Glycol Make Up System and Drain Vessel

Glycol from TEG drain vessel is pumped to TEG storage tank by  TEG Drain Vessel Pump in the drain vessel. The lean glycol in the storage tank is used to make up loss of glycol in the regeneration system. TEG is pumped from the TEG storage Tank to the TEG accumulator vessel by TEG Make up pump. The TEG make up pump operates intermittenly with design capacity 5.5 m3/hr.

The Logic Behind The Magic." Glycol Dehydration System 8"

TEG Vent Exchanger Outlet Temperature Control

The TEG Vent Exchanger outlet temperature is controlled by TC-FC cascade. The outlet temperature is influenced by Heating medium from TEG Reboiler

The Logic Behind The Magic." Glycol Dehydration System 7"

TEG Reboiler
Rich glycol from TEG Still column flows into the shell side of glycol  reboiler. Hotoil comes from hot oil supply header is used as heating medium in reboiler tube side. The renegerated flows by gravity across the length of the TEG reboiler and enters the Stripping gas column operate at 204.4 degC at atmospheric pressure. TEG loss is reduced by increasing the flow of the rich TEG through tube side of TEG reflux condenser.

TEG Vent Exchanger
Water vapour from the shell side of the TEG reflux condenser passes through the shell side of an 8.36 kW double pipe type TEG Vent Exchanger before letting it go to the acid flare system. Water vapour is heated up to 150 degC by the hot oil passing through the tube side of the TEG vent exchanger for this purpose. The temperature of water vapor of the acid flare is controlled by an FC TC cascade control loop.

Stripping Gas Column

 The use of Stripping gas column is provided to reduce the water content of the regenerated glycol by counter current contact with hot fuel gas flowing upward through the stripping gas column. The stripping gas also reduces the partial pressure of the vapour in the TEG reboiler. Hence increasing the regeneration capability of the TEG reboiler. Regenerated glycol flows from the bottom of the stripping gas column by gravity into the hairpin type Hot Lean Rich TEG exchanger where it is cooled to approximately 124.8 degC and then goes into the other haipin type Cold Lean Rich TEG Exchanger where it is further cooled to approximately 85.55 degC.


TEG Accumulation Vessel
Lean glycol from Cold Lean/Rich TEG exchanger is sent to the TEG accumulator vessel. The TEG accumulator vessel is sized for a 22.3 minutes residence time between low-low liquid level and high-high liquid level, of lean glycol at pump maximum capacity (33 USgpm). The TEG accumulatoe vessel provides storage capacity for the TEG circulation pumps.

TEG Circulation Pumps
The TEG circulation pumps are rotary gear type pumps, operating at normal discharge pressure of approximately 52.06 Barg. The lean glycol from the discharge of the TEG circulation pumps is sent to the 235.8 kW TEG cooler,

TEG Cooler
The TEG coller is an air cooler where the lean glycol is cooled to 48.25 degC and sent to the TEG contactor for re-use. 2x5 kW fans are used to cool the lean TEG

The Logic Behind The Magic." Glycol Dehydration System 6"

TEG Regeneration Package Control


 

The Logic Behind The Magic." Glycol Dehydration System 5"

TEG Regeneration Package

TEG Reflux Condenser

TEG Reflux Condenser is located at the top of the TEG Still column and used to maintain the temperature of the steam leaving for condenser. Rich glycol flowing through the TEG reflux condenser coils is warmed to 49.48 degC by steam and glycol vapour present in the steam is condensed on the shell side.
  

The Logic Behind The Magic." Glycol Dehydration System 4"

TEG Overhead KO drum Control

TEG Overhead KO Drum Level Control

Gap Control is applied to the following level control.
On normal process valve, The control valve controlled normaly by level control. If the PV Rise Up Until Reach High Level Alarm. Controller   will send command to control valve for 100% open. If the PV decrease until reach low level alarm, controller will send command to control valve for 0% Close (Shut Off).
 

The Logic Behind The Magic." Glycol Dehydration System 3"

TEG Overhead Knock Out Drum

Dehydrated gas leaves the Glycol contactor and fed to TEG Overhead KO drum. The dehydrated gas leaving top of the TEG Overhead knock out drum passes through a Mist eliminator to remove entrained glycol. The TEG Overhead KO drum is designed to operate at 44.44.26 barg and 45.97 degC. Gas from the TEG Overhead knock out drum is sent to Gas/Gas Exchanger. TEG recovered in the KO drum is sent to the TEG Flash Drum in the outlet line of the KO drum is controlled by a LV which is operated by on-off configuration

The Logic Behind The Magic." Glycol Dehydration System 2"

Glycol Contactor Level Control

Gap Control is applied to the following level control.

On normal process valve, The control valve controlled normaly by level control. If the PV Rise Up Until Reach High Level Alarm. Controller   will send command to control valve for 100% open. If the PV decrease until reach low level alarm, controller will send command to control valve for 0% Close (Shut Off).

Instrument Control Function Detail

TEG Cooler

The different temperature between TEG contactor inlet and TEG cooler inlet is monitored by TDC. The different temperature will be calculated and use for controlling TEG cooler.

Instrument Control Function Detail

Other controllers
The controller will used simple loop type with direct -reverse acting list as follows:

The Logic Behind The Magic." Glycol Dehydration System 1"

Sweet gas from Amine Overhead KO drum will flows to Triethylene Glycol Contactor where it will have its water contect reduced by contact with triethylene glycol solution. The Glycol unit consists of Glycol Contactor and Glycol Overhead Knock Out Drum.

Triethylene Glycol Contactor.
Sweet gas from Amine Overhead Gas Knock Out Drum is sent to the Glycol Contactor through the integral scrubber for removing free liquids, water and hydrocarbon condensate from the gas. Incoming gas is evenly distributed over the cross sectional area by an inlet distributor. In this distributor, inlet momentum of gas-liquid mixture is broken to enable disengagement of gas from liquid. The integral scrubber consists of mist eliminator to remove the free liquid present in the incoming gas. It is designed to operate at 45.16 barg at 43.85 - 444.25 degC. The hydrocarbon liquids from the separator leave from the bottom of the vessel. The flow is controlled by an LV

After the removal of free liquids, the gas enters the absorber section, Chimney trays are provided for proper distribution of the gas through the column. Dehydration of the gas takes place across height structured packing, against a counter current flow of lean Tri-Ethylene Glycol.

The dehydrated gas leaves to of the column passing through vane pack, mesh, and mist eliminator are provided to remove glycol before leaving the tower. The glycol is ditributed across the packing with high efficiency liquid distributor. As the glycol flows down the surface of the structured packing, it absorbs water from the gas. Rich glycol is collected on the top of the chimney tray and is discharged under level control valve LV to the TEG reflux condenser. Located in the TEG regeneration package.

The Logic Behind The Magic."H2S Removal system 7"

Amine Drain System.

 The drain system of amine unit is a closed system, where each drain line is tied into an underground pipe header, which flows into the Amine Drain Vessel. The system, from the piping, equipments and instrumentations, is hard piped and freely drained into Amine Drain Vessel.

The Amine Drain Vessel is located in the sump pit as the TEG Drain Vessel. The Amine Drain vessel is designed to store the entire liquid inventory of amine system. The vessel is constructed from CS lined with 3 layers epoxy lining and equipped with fireproofing insulation to anticipate pool fire condition in emergency case.

To prevent degradation of the solvent by air ingress, fuel gas blanketing is provided to drain vessel controlled by PCV-A, set at 0.27 barg and PCB-B set at 1.75 barg to release gas in case of built-up pressure at the vessel is maintained at about 0.1-0.3 Barg.

As the pit is open, rainwater could accumulate in the pit. Sum drain pumps are provided to pump the rain water out from the pit.

The drained solution is collected in the sumps provided at the following points where potential leakage or spillage is considered.

When amine solution liquid level is too high, the amine solution can be pumped back to the Amine Surge Vessle with the Amine Drain Vessel Pump.

Fail Safe Design Maintainability In Remote Platform?

Shutdown platform occurred during my site trip last year in one of the remote offshore wellhead platform. ESD alarm on the operating console showed that the shutdown is triggered  by one of the push button on the cellar-deck.


The the problem comes, every time the operator wants to reset the ESD logic. The push button fail safe  mode which in de-energized status keep sending shutdown command and it cannot be re-setted.
Since the override command is only accessible to authorised maintenance personnel. the operator cannot access the overrides command and he started to panic

The Logic Behind The Magic."H2S Removal system 6"

Amine Circulation System Control Narrative

The Amine Regenerator Overhead Cooler outlet temperature is controlled by TC. When outlet temperature of Amine Regenerator Overhead Cooler is decreases, VFD Speed Control is controlled by TC for preventing from more decreasing and increasing temperature.

 

Other controllers
The controller will used simple loop type with direct -reverse acting list as follows:

The Logic Behind The Magic."H2S Removal system 5"

Amine Circulating System.

The hot lean amine existing the amine regenerator flows into the lean side of lean/rich amine exchangers by means of heat lean amine pumps where heat is exchange with the cold rich amine from the flash drum. The cooler lean amine is further cooled to 45 degC in the lean amine air cooler. This is an air cooler utilizing stadard finned tubes and electric motor driven fans. Air cooler is equipped with bug screens and eazh bank includes one variable frequency drive (VFD) fan motor to assist in achieving close temperature control of the lean amine.

The Logic Behind The Magic."H2S Removal system 4"

Amine Regenerator Overhead Cooler Control Narrative

The Amine Regenerator Overhead Cooler outlet temperature is controlled by TC. When outlet temperature of Amine Regenerator Overhead Cooler is decreases, VFD Speed Control is controlled by TC for preventing from more decreasing and increasing temperature.

 

Other controllers
The controller will used simple loop type with direct -reverse acting list as follows:

The Logic Behind The Magic."H2S Removal system 3"

Amine Regeneration System.

The rich amine solvent from the contactor bottom flows to the Amine Flash Drum through level control valve. This level will let the rich amine pressure down from 46.3 to 5.5 barg. This is where the first stage of degassing of the solvent takes place. The drum is designed to allow the break out of the H2S and CO2. The drum is designed for liquid removal efficiency of 99% or greater for liquid droplet size of less then 70 micron, limiting the liquid carryover in the gas to be less than 0.1 gal.MMSCF, maximum oil carryover in the outlet water is 1% weight and maximum water carryover in the outlet oil is 1% weight.

Rich amine solution from the flash drum, at 31 degC flows into the lean/ rich amine exchangers and  is heated to about 93.5 degC. Proir entering the exchanger; the rich amine is filtered at the rich filter to removed any contaminant particles.

The Logic Behind The Magic."H2S Removal system 2"

Amine contactor System Control Narrative

Amine Contactor Inlet KO Drum level controller

Gap Control is applied to the inlet KO Drum level control. On normal process valve, the control valve controlled normally by level control. If PV decrease untuil reach low level alarm the controller will send command for 0% close to control valve, and if PV increase until high level alarm. The controller will send command for 100% open.

The Logic Behind The Magic."H2S Removal system 1"

The H2S removal system is usually utilizes Methyl Diethanolamine (Ucarsol) solvent to absorb content in the gas stream and reduce H2S concentration to 10 ppmv to meet sales gas specification.

 Ucarsol solvent is formulated to operate at a 15 +/- 5 % wt. Operating above this concentration range can lead to viscosity related problems such as in efficient acid gas absorption, hydrocarbon entraintment, poor heat transfer efficiency and higher pumping requirement. Operating below this will result in increase circulation rate and higher reboiler duty requirement. The system also includes regeneration of Ucarsol solvent to strip H2S gas and H2S tail gas is further treated in the thermal oxidizer prior disposal.

The Logic Behind The Magic."Liquid Separator and condensate coalescer package"

Separator
The separation of water and hydrocarbon liquids takes place in the liquid separator. The separated water is routed to the condensate stabilization unit via condensate coalescer package.

The liquid separator is basically a three phase separator that has specific internals to allow good performance in oil-water-gas separation. Baffle distribution and plate pack are provided for oil-water separation and vane pack mist eliminator is enable for gas liquids separation.

The Logic Behind The Magic."Slug catcher and Inlet Separator".

The fluids at receiving facility flow to slug catcher, where gas and liquid are separated. The feed gas line is also equipped with a connection and injection quill for methanol injection to prevent hydrate formation.

The separation of gas from the liquid is occur in the slug catcher.in this case finger type slug catcher is usually used.

The Logic Behind The Magic."Onshore Processing Facility"

Wellhead fluids are routed to onshore processing facilities through the export pipeline. Onshore processing facilities will processes fluids from wellhead. The onshore processing facilities usually comprises of the following facilities:

The Logic Behind The Magic."Seal Gas System"

Seal gas will be provided to each turbine driven compressor as a barrier between the process gas lift and the dry gas seals. The primary source of seal gas is from  the discharge of the 2^nd stage gas lift compressor. The gas is regulated by inlet control valves (2x100% configuration) to maintain the pressure at 95 barg.

The seal gas scrubber will remove any entrained liquid from the supply gas. The filter coalescer is provided to removed 99.9% any liquid / solid particle greater than equal to 2 micron.  Liquid drop is removed in the seal gas scrubber located immediately downstream of the pressure control valve. 

Invert, always invert

If f and f⁻¹ are inverses, then the graph of the function

is the same as the graph of the equation

  the solution of many hard problems can be clarified by re-expressing them in inverse form.

"Invert, always invert",Carl Gustav Jacob Jacobi 

The Logic Behind The Magic."Fuel Gas System"

Fuel Gas is normally supplied from the Compressor discharge with back-up take-off from MP separator gas outlet header. At start-up, the gas wells should be run first to provide fuel gas. Alternatively, gas may be sourced from Separator.

The Logic Behind The Magic."Open Drain System"

The Open Drain System is intended to collect and process atmospheric pressure drains from equipment or from deck drainage prior discharge to the environtment. This includes any liquids such as process drain, spill, and overflows.

There are two sub system to the open drain system. one is received drains from hazardoud area and the other receives drains from non hazardous areas. Drains from both systems are routed to the open drain tank which is overflow weir type separator. The overflow water will flow to the open drain caisson while the oil will flow to the internal oil compartment within the tank. The recovered oil will be pumped to the LP flare KO drum via open drain pump.

The Logic Behind The Magic."Flare System "

High Pressure (HP) and Low Pressure (LP) flare system are provided to safely dispose of gas relief valve, starting gas, and blowdown from vessel. Each system consists of a gathering header, KO drum, a flare tip and ignition system, During normal operation, the flare system should only have a small purge gas flow, The HP and LP KO drums separate liquid and gas from the flared gas system.

HP Flare System
The HP Flare KO drum is designed to handle the capacity of flare system and accommodate the liquid knockout under the maximum relieving scenario. i.e. during emergency total platform blowdown

The Logic Behind The Magic."Reject Oil Tank and pumps

The reject oil vessel receives recovered oil from the produced water hydrocyclone and vessel. Reject oil  pump is provided to transfer oil from the reject oil collection vessel back to the separator. The pump speed is regulated to maintain oil level in the vessel.

The Logic Behind The Magic."Gas Turbine Compressor 2"

Compressor Surge Detection and Avoidance

The surge condition occurs when the compressor does not have enough flow to produce sufficient head and the gas in the discharge line will flows back into the compressor. This cycle of flow is called surge.
An anti surge valve is designed for surge control by recycling the flow to the suction line of  compressor.
The  input to the anti surge control are flow differential pressure across the flow meter, compressor suction and discharge pressures (Ps, Pd), temperatures,  and the anti surge valve position feedback.

The surge detector monitors flow differential pressure pulses across the flow meter. Flow pulse may indicate a compressor surge event. When a flow pulse occurs, the ASC step changes the command to the Anti surge valve to 15% more open to increase the flow into the compressor to prevent any possible surge. If the ASC detects 5 pulses within 10 second the train is cooldown shutdown.

The surge avoidance fuction is based on the reduced head vs. reduced flow factor.

The surge margin takes input of pressure, temperature and flow to calculate compressor surge margin which is defined to be distance from the operating reduced flow factor to the reduced flow factor at the surge limit line as a percentage.  The ASC compares the operating flow factor to keep the compressor operating a safe distance away from surge.
The ASC will begin to open the Anti surge valve if the surge margin drop below 10%.
PI algorithm is used to close and open the valve. One set of gains is used to slowly close the anti surge valve and another set to quickly close the anti surge valve. If the surge margin drops below 10% the ASC override manual modes.

 

The Logic Behind The Magic."Gas Turbine Compressor 1"

Compressor
Compressor is used to flow gas from a lower pressure to a higher pressure system. Compressor are used to compress the gas for sale or on long pipelines to restore pressure drop lost to friction.

Usually the compressor is centrifugal compressor which takes gas from the suction scrubber out oulet and compress is to adjustable pressure. usually  the compressor is driven by gas turbine. Suction pressure controller within the package unit control panel will maintain the pressure at suction scrubber by regulating the compressor turbine speed control.

 Typical gas turbine cycle

 

The Logic Behind The Magic. “1st Stage Compressor Suction Scrubber"

The purpose of suction scrubber is to remove liquid prior to feeding gas into the 1st Stage compressor. Collected liquid is routed to HP flare KO drum, The liquid level in the scrubber is controlled using GAP control by opening/ closing the liquid outlet control valve

The Logic Behind The Magic."Produce water treater vessel and injection pump"

The separated produced water from the hydrocyclone is routed to the Produced Water Treater Vessel to further enhance oil and water separation, The Primary function of treater vessel is to degas the produced water. As the pressure is reduced from the hydrocyclones, the gas bubles that are liberated rise within the water in the degasser and capture and separate the small, finely dispersed oil droplets. Larger oil droplets are removed by internal weir.

After treatment, produced water is re-injected back into reservoir via the Produced Water Injection Pumps. produced water treater process schematic is shown as following:

The Logic Behind The Magic."Produce water Hydrocyclones"

The purpose of the Produced water treatment is to de-oil the produced water before injection back to reservoir. Produced water treatment is designed to achieve the discharge oil-in water to meet the specification (e.g. 25 mg/L (ppmV). A common oil in water analyzer is usually installed for monitoring and recording of oil content in water from Produced oil water treater vessels
Under normal operating condition, produced water from the MP separators flows into hydrocyclones and the produced water flow is regulated by the interface level controller in the Separators. 

The hydrocyclone is operated under differential pressure ratio controller i.e the ratio of  (hydrocyclone inlet pressure minus reject oil stream pressure) to ( hydrocyclone inlet pressure minus hydrocyclone water outler pressure).  The DPR controller is set at adjusted value and will continuously adjust the hydrocyclone reject oil control valves to achieve the DPR set point.

The Logic Behind The Magic."Separators Operational and Control Philosophy"

The Separators are designed to operate in parallel with a flooded weir. The normal liquid level is maintained above the weir by a level controller. The oil-water interface level is maintained by the interface level controller. The separated gas is used for for gas lift and fuel gas with the balance to the compressors. Oil from the separator is delivered to the Separator oil pumps and combined with the compressed gas. Water is sent to Produced water treatment package.

The Logic Behind The Magic."Basic System Configuration"

 Typical Oil and Gas Production Process

The Logic Behind The Magic. “Control Function Block "

Process quantities (level, flow, pressure, ..etc) in plant need to be maintained at target value and a difference from these values could result in a dangerous condition arising or loss production.

To maintain these process quantities condition over an extended period of time without any operator involvement. Automatic control system is usually installed and used.

The element of these control system (loop) are:

1. Transmitter: Process variable is measured by the primary element of the transmitter and the measured signal is converted to electric 4 to 20 mA signal.
2. Controller: Controller receive a signal from the transmitter and compares this value with the set point and computes the output signal to achieved the set point.
3. Final Control Element: Correction device in the control loop. Usually a valve

The Logic Behind The Magic. “Production Well"

A well drilled to find and produce oil or gas in an unproven area  to find a new reservoir

Reservoir development process is comprises of 5 phase:

1. Well construction

2. Drilling

3. Casing

4. Cementing

5.  Completion

The Logic Behind The Magic. “Line Monitored Signal conditioning"

Signals from the various field F&G detectors and push button are processed by the Safety Shutdown System by means of dedicated functions implemented as standard within the Safety Shutdown System.

The line monitoring facility discriminates between open-circuit, short-circuit and true alarm conditions.

the  line monitoring faults is handled as follows:

The Logic Behind The Magic. “Emergency Shutdown System (ESD) Operating Philosophy 3"

Start-up and Maintenance inhibit/ Override

In order to be able to start-up equipment or sections process, it is necessary to inhibit some inputs to the ESD system, as sensor signal may be in abnormal state prior to start-up and could cause a shutdown. Such inhibits are designated as "start-up inhibits".

While Maintenance inhibits are set from the  maintenance / inhibit console for maintenance purpose

Each inhibit function is reset automatically either by the sensor signal reverting to normal state or after a predetermined time delay. The automatic resets are achieved by the Safety Shutdown System.

The Logic Behind The Magic. “Emergency Shutdown System (ESD) Operating Philosophy 2"

Resetting philosophy

Further to a shutdown, the related ESD levels need to be individually and manually reset by the Operation Console operator. The ESD level can be reset only if the upper ESD level is in normal condition.

Resetting sequence is as follows :

·         The operator is informed on the ESD and process displays that the ESD level can be reset

·         ESD level alarm return to normal conditions only when all ESD causes have disappeared or have been inhibited and the ESD level reset is carried out on the ESD display of theOperation Console

The Logic Behind The Magic. “Emergency Shutdown System (ESD) Operating Philosophy 1"

The Emergency Shutdown (ESD) System is designed to protect the personnel, plant, equipment and the environment against pollution. The purpose of the ESD system is to monitor process safety parameters and activate or shutdown the process system and/or the utilities if these parameters deviate from normal conditions.

Usually there are several levels of shutdown:

·         ESD 0 :                       Total emergency shutdown  with abandon of platform

·         ESD 0.1 :                    Black shutdown

·         ESD 1 :                       Total plant emergency shutdown

·         ESD 2 :                       Total process shutdown

·         ESD 3 :                       Local unit shutdown

The Logic Behind The Magic. “Blow Down Valve"

Blowdown valve (BDV) is a block valve that is actuated through the ESD system which is situated in the system requiring pressure depressurisation during plant emergeny or shutdown. BDV is not used in process control.

BDV is typically with shutdown valve but in the reverse condition.(BDV is Fail Open valve, SDV is Fail Closed valve)

The Logic Behind The Magic. “Shut Down Valve".

The isolation of sections of plant will typically be an engineering judgement based on:
1. The purpose for the isolation; either maintenance/operation or shutdown
2. The design condition of the section, particularly pressure
3. The nature of the fluid in the section, e.g. flammability, toxicity etc

Isolation of a section for shutdown purpose will always consist of a single, actuated valves on the perimeter, which will respond to a shutdown signal(s) from ESD systems. Single shutdown valves are normally sufficient for the event initiating the shutdown and associated risk

The Logic Behind The Magic. “Smoke and Heat Detectors"

There are two types of smoke detectors, each having different applications

Ionization Smoke Detectors detect the presence of smoke by means of a small ionization chamber and a source of ionizing radiation. Ionization Smoke Detectors are generally better at detecting smaller smoke particles such as that produced by rapidly burning fires, but are less sensitive to the larger smoke particles generated by smouldering fires, etc.

Photoelectric (Optical Point) Smoke Detectors detect the presence of smoke by means of a small light source and a separate photoelectric light sensitive cell housed within a sensing chamber. Photoelectric Smoke Detectors are generally more sensitive to larger smoke particles such as that generated by dense smoke or smouldering fires, but are less sensitive to small particles of smoke found in rapidly burning fires.

The Logic Behind The Magic. “Open Path Type Gas detector”

Open Path type gas detector devices measure the sum of the hydrocarbon molecules along a narrow beam, the configuration for displaying the reading from an IR beam gas detector is as follows:

Display in LEL-meters which is an integral of percentage LEL as multiplied by the length of the beam.  This is in effect a direct reading of what the device is measuring i.e. the total number of hydrocarbon molecules along the length of the beam.

Alarm levels should be set at a low level but such that spurious alarms are avoided, typically:

·         High level gas – 1 LEL.m,

·         High-High level gas – 2.53 LEL.m 

The Logic Behind The Magic. “IR Flame Detectors" The Logic Behind The Magic. “IR Flame Detector”. ”.

Fire detection is required for process equipment and heat generating utilities, specifically where liquid hydrocarbons may accumulate.  For areas where there is a significant fire risk, additional detectors employing diverse techniques may be considered.

The fire detectors should be selected to suit the conditions and to provide the earliest reliable warning. The suitability of the fire detector is dependant upon the characteristics of the fire, which are determined by the materials involved and their rate of combustion.

Triple Band IR Flame Detectors are considered best practice for flame detection.

Sample of IR Flame Detectors criteria and requirement is shown below.

The Logic Behind The Magic. “Hydrogen Sulphide detectors”

Fixed toxic gas detection is usually provided throughout the platforms due to the significant levels of H₂S in the process fluids being handled and the need to ensure the rapid detection of H₂S gas hazards to warn personnel.

Electrochemical type is widely used and installed in areas where the accumulation of H₂S is likely and at all ventilation intakes

High or High High gas detection by a single H₂S gas detector shall only initiate alarms whereas a coincident High High gas detection by two or more detectors shall initiate a confirmed gas condition with subsequent actions in accordance with F & G Cause & Effect Matrix.

The Logic Behind The Magic. “Gas detector”.

Gas detectors is installed in the platform according to the type and nature of perceived hazard. For example, IR point type gas detector only measure flammable gas concentrations at certain points and there is no way of knowing the composition of the gas cloud between the point detectors, it is therefore necessary to initiate alarms and executive actions well before the concentration at any point reaches 100% of the LFL. The settings shall be as follows:

·         High level gas (process areas) – 20%LEL,

·         High-High level gas (process areas) – 50%LEL,

These type of detector usually have 7 signals and status that are shown in the control room,

1. Faulty Status
2. Calibrate alarm
3. High gas alarm
4. High  gas exec action
5. High-high alarm
6. High-high gas exec action.
7. Inhibit signal

Pipe Reducing Factor

Holden wants to install 1" valve in 2" size pipe. But he wonder what are the reducing factor that he needs to consider. So he began to make the calculation.


Cv with piping geometric factor consideration equations are:



         
             Where Fp (R)

 

Where:

 d :           Valve inlet diameter 

D            :           Internal diameter of the pipe 

K            :           Head loss coefficient of a device, dimensionless

N2           :           constant to suit the measurement unit, 890