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GMS Interneer Co., Ltd. is a solution provider, a representative, and a trusted partners to oil & gas equipment users in Thailand as well as world-class manufacturers worldwide.
Serving end users, we look for innovation and solutions from world class engineering Equipment Company to ensure the specific need is met. Partnering with worldwide manufacturers, we look for business opportunity by utilizing technical strong point of each product to complement and to enhance our customer production.
https://www.gmsthailand.com/ (https://www.gmsthailand.com/)
บริษัท จี เอ็ม เอส อินเทอร์เนียร์ จำกัด
อาคารซันทาวเวอร์สบี ชั้น 28 เลขที่ 123
ถนนวิภาวดีรังสิต แขวงจอมพล เขตจตุจักร
กรุงเทพ 10900
GMS Interneer Co.,Ltd.
28th Floor, No. 123 Suntowers Building B
Vibhavadi-Rangsit Road, Chompol,
Chatuchak, Bangkok 10900
Email : contact@gmsthailand.com
Tel : +66 (0)98 967 6383
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Using Cryogenic tank and maintenance
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Liquefied gases are utilized in a variety of industries, including metal processing, medical technology, electronics, water treatment, energy production, and food processing. Today, an increasing number of these industrial gases are supplied to clients in liquid form at cryogenic temperatures, allowing them to be stored on-site for subsequent use.
Cryogenic tanks are used to keep cryogenic liquids safe. Cryogenic liquids are usually liquefied gases with temperatures of -150 °C or below. Oxygen, argon, nitrogen, hydrogen, and helium are all common byproducts. Cryogenic tanks may also be used to store liquified gases, such as liquefied natural gas (LNG), carbon dioxide, and nitrous oxide. These are gas used in a variety of industries such as metal processing, medical technology, electronics, water treatment, energy production, and the food industry. Cryogenic liquids are also utilized in low temperature cooling applications such as engineering shrink fitting, food freezing, and bio-sample storage.
Cryogenic tanks are thermally insulated, usually with a vacuum jacket, and are developed and built to exacting standards in accordance with international design regulations. They may be stationary, mobile, or transportable.
Static cryogenic tanks are intended for use in a permanent position; however, transportable compact tanks placed on wheels for use in workshops and labs are included. Because static cryogenic tanks are usually classed as pressure vessels, new tanks and their related systems will be built and installed in compliance with the Pressure Equipment (Safety) Regulations. Non-pressurised open neck vessels (Dewar flasks) are also available for applications needing direct access to the liquid. To suit the varied needs of the users, the tanks are available in a variety of sizes, pressures, and flow rates. Tanks used to transport cryogenic liquids must conform with the Carriage of Dangerous Goods and Use of Transportable Pressure Equipment Regulations.
Cryogenic tank use, operation, and maintenance
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Cryogenic Liquid Vacuum Storage Tank
Cryogenic tanks must be operated and maintained in accordance with all applicable laws, such as the Pressure Systems Safety Regulations for static tanks and the Carriage of Dangerous Goods and Use of Transportable Pressure Equipment Regulations for transportable tanks. Cryogenic tanks must be maintained and handled by qualified individuals.
The Regulations require cryogenic tanks to undergo regular inspection, routine maintenance, and periodic formal examination for static tanks. An inspection and maintenance schedule should be developed to guarantee that the tank is in safe working order during official examination periods. This will comprise a Written Scheme of Examination to be developed by a competent person(s), as well as periodic formal exams to be held in line with the scheme.
Transportable tanks need periodic inspection and testing, which may only be performed by an Inspection Body authorized by the National Competent Authority, Department for Transport, in every country.
All inspections, exams, and tests are recorded, and records must be maintained throughout the tank’s entire life.
Cryogenic tank users and owners have legal obligations and a duty of care to ensure that their equipment is maintained and operated safely. A gas provider will only fill a tank after determining that it is safe to do so. Routine safety checks must be performed by the user. A little amount of icing and ice may be seen while in use. Small amounts of ice should not be a reason for worry, but the amount of ice should be checked on a regular basis. If ice continues to accumulate, de-icing should be performed to avoid excessive ice accumulation
Repair and modification of cryogenic tanks
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LNG Cryogenic Liquid Lorry Tanker
Any repair or modification to a cryogenic tank must be carried out exclusively by a qualified repairer in accordance with the design codes to which it was built, taking current rules and legislation into consideration. Such repairs or changes must not jeopardize the integrity of the structure or the functioning of any protective measures. All repairs and changes must be recorded and maintained on file for the life of the tank.
Revalidation of cryogenic tanks
Cryogenic tanks must be evaluated on a regular basis to verify that they are safe for ongoing use. A Competent Person shall determine the revalidation period, which shall not exceed 20 years. Because of the nature of their function, mobile tanks should be rented for a shorter length of time. When a tank is revalidated, a report is generated that must be maintained alongside the tank data for the duration of the tank’s life.
Cryogenic tank disposal
Because certain cryogenic tanks contain dangerous materials in their vacuum area, such as perlite, tanks should only be disposed of by a qualified and experienced disposal firm. As pressure equipment, all equipment must be made non-reusable.
https://www.gmsthailand.com/blog/using-cryogenic-tank-and-maintenance/ (https://www.gmsthailand.com/blog/using-cryogenic-tank-and-maintenance/)
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What is the operation of a CHP power plant ?
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Cogeneration is the simultaneous production of two or more types of energy from a single fuel source. It is also known as combined heat and power, distributed generation, or recycled energy. Cogeneration power plants are typically 50 to 70 percent more efficient than single-generation facilities. In practice, cogeneration is the utilization of what would otherwise be wasted heat (such as a manufacturing plant’s exhaust) to generate extra energy advantage, such as heat or electricity for the building in which it is running. Cogeneration is beneficial to both the bottom line and the environment since recycling waste heat prevents other polluting fossil fuels from being burnt.
Although combined heat and power (CHP) technology is often referred to as cogeneration, there are significant distinctions. Cogeneration is the process by which a simple cycle gas turbine generates electricity and steam, as well as steam utilized in other processes such as drying. The steam, however, is not utilized to power a steam turbine.
CHP combined-cycle power plants may generate both electricity and usable heat energy from a single fuel. Thermal energy (steam or hot water) collected may be utilized for operations such as heating and cooling, as well as generating electricity for various industrial uses. CHP is used by manufacturers, municipalities, commercial buildings, and institutions such as universities, hospitals, and military sites to cut energy costs, improve power dependability, and minimize carbon emissions.
What is the process of cogeneration ?
A cogeneration plant is similar to a CHP plant in that it generates both electricity and heat. Cogen technology, on the other hand, differs from CHP in that it generates energy using a simple cycle gas turbine. The exhaust energy from the gas turbine is then utilized to generate steam. The steam is then utilized entirely in other processes, rather from being channeled to operate a steam turbine as in CHP.
What is the operation of a CHP power plant ?
A CHP power plant is a decentralized, energy-efficient way of producing heat and electricity. CHP plants may be installed in a single building or business, or they can provide electricity for a district or utility.
In CHP, a fuel is utilized to power the primary mover, which generates both electricity and heat. The heat is then utilized to bring water to a boil and create steam. Some of the steam is utilized to power a process, while the rest is used to power a steam turbine, which generates more power. In a cogen application, the steam is completely used in a process that generates no extra electricity.
Advantages of Combined Heat and Power
When compared to traditional energy generation, a CHP power plant may provide many benefits and advantages, including:
- Greater efficiency: CHP generates both electricity and heat while using less fuel than conventional energy plants. Furthermore, it collects heat and steam to produce extra power, reducing the demand for fuel even further.
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- Lower emissions: Because CHP systems consume less fuel, they may decrease greenhouse gas emissions and other air pollutants.
- Lower running expenses: The efficiency of CHP lowers down operating costs and may offer a hedge against rising energy prices.
- Dependability: Because CHP is an onsite energy plant, it reduces dependence on the energy grid and may provide greater energy security and reliability of power generation even in the event of a catastrophe or grid interruption.
- District heating: Cogeneration systems are used in district heating power plants to supply both energy and heating to local facilities and residences. Unused steam is channeled to generate extra electricity when a CHP system is utilized for district heating.
- Industrial manufacturing: Industrial CHP plants enable businesses that use a lot of energy to generate their own steady supply of electricity while improving efficiency and lowering fuel usage. CHP systems may power a broad range of industrial and manufacturing operations while also producing usable energy such as high-pressure steam, process heat, mechanical energy, or electricity.
- Commercial structures: From commercial office buildings and airports to casinos and hotels, CHP plants assist to provide clean, dependable electricity that helps fulfill baseload needs while lowering energy costs. Steam heats and cools the environment while also generating energy to power lights and electronics.
- Institutions: Colleges and universities, hospitals, jails, military posts, and other institutions depend on CHP plants to fulfill their electrical and thermal energy requirements, as well as to improve power reliability. The CHP system may substantially reduce the costs and emissions associated with conventional forms of power generation.
- Municipal applications: CHP is ideal for municipal wastewater treatment facilities. Anaerobic digestion generates biogas in these facilities, which may be used to power onsite generators.
- Residential: CHP systems can power energy-intensive multifamily buildings or assist single-family houses fulfill their energy requirements.
CHP for big structures and infrastructures
combined heat and power generation (CHP) effectively contributes to the production of electricity for hospitals, airports, and other big institutions. CHP generating solutions not only help operators avoid substantial supply and distribution losses, but they also save 40% more fuel than separate generation and may help improve overall efficiency, profitability, and environmental responsibility.
https://www.gmsthailand.com/blog/what-is-the-operation-of-a-chp-power-plant/ (https://www.gmsthailand.com/blog/what-is-the-operation-of-a-chp-power-plant/)
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Absorption Chiller
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Absorption chillers, as opposed to traditional chillers, utilize waste heat from other processes or equipment to drive a thermodynamic process that enables water to be cooled and distributed for HVAC requirements. Water is typically combined with either ammonia or lithium bromide in lieu of traditional refrigerants, with lithium bromide being the more popular choice since it is non-toxic.
Important factors to consider while building an absorption chiller
Because absorption chillers do not use electric compressors, they may offer considerable cooling capacity to a facility while not contributing to peak energy demand. The most important factor to consider when evaluating the application of such a chiller is that they do need a substantial and constant supply of waste heat to operate. Although industrial manufacturing facilities are the most apparent choices, other locations like as university campuses, bigger hospital complexes, or large hotels may frequently benefit significantly from adding an absorption chiller.
The advantages of using absorption chillers
The primary refrigerants used in absorption chillers do not contribute to global warming or ozone depletion. An absorption chiller may help the facility save money on energy, hot water, heating, and cooling. The absence of compressors in the machine reduces noise and vibration in the building, resulting in a peaceful atmosphere with excellent dependability.
An absorption chiller is powered almost completely by heat that would otherwise be wasted. It does not need electricity to produce chilled water and heat. It will not be necessary to provide nearly as much capacity in an emergency backup power system.
The Science of Absorption Chilled Water
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An absorption chiller has a condenser, generator, evaporator, absorber, and heat exchanger. The absorber initially holds lithium bromide solution. It will be forced via the heat exchanger into the generator tank on the chiller’s top. The chiller’s generator will utilize heat from the sun or hot water, steam, and flue gas from other systems. Heat separates lithium bromide and water. Water steadily evaporates and rises to the condenser, while lithium bromide sinks.
The lithium bromide will return to the absorber through a conduit. The vapor will next travel via a cooling coil in the condenser. Following this, the vapor is condensed to the condenser bottom.
The water is then sent to the evaporator, where it remove heat out of the chilled water and becomes the vapor.
When water evaporates, it takes away the heat. The vapor is then absorbed by lithium bromide solution in the absorber. The mixture flows through the heat exchanger and return to the generator.
An absorption chiller produces chilled water with little energy input. It will continue to remove heat from the building throughout the heating and cooling cycle.
More about the working concept
Firstly, a mixture of lithium bromide and water in the absorber is pumped through the heat exchanger to the generator
In order to separate the mixture in the generator, heat source from hot water, steam or flue gas will change water to vapor leaving the lithium bromide behind. Then, the vapor will flow into the condenser.
The lithium bromide won’t be left as a waste. It will form as a liquid and sink to the bottom of the generator. After that, the lithium bromide liquid flows down to the absorber once more through the heat exchanger. This liquid will spray over the absorber, so it will absorb vapor in the absorber again.
Meanwhile, the vapor from the generator is condensing into a refrigerant in condenser . Because of that, it meets with a cooling coil, whose water from cooling tower flows inside to remove heat from the vapor.
Next, the refrigerant kept in a tray flow through a pipe to the evaporator. A fixed orifice controls the volume flow rate of refrigerant. Due to vacuum condition in the evaporator, the boiling temperature of water will be quite low.
Finally, the chilled water which carries all the unwanted heat from the building or any cooling process flows through the evaporator to extract the unwanted thermal energy by spraying refrigerant over the chilled water line a. Therefore, the chilled water temperature will be decreased from 12°C to 7°C and refrigerant vapor is moving to the absorber to be absorbed with absorbent agian.
Making the most of absorption chillers
While absorption chillers are superior to traditional cooling techniques in the areas we’ve previously discussed, appropriate and frequent maintenance is required for optimum operation. This is the only method to guarantee that the equipment lasts the whole 25 years. A chiller will perform flawlessly if personnel concentrate on the following areas of maintenance: controls, mechanical components, and heat transmission components. Here are a few examples of areas that need attention:
• Pump shaft seals- inspect for wear • Refrigerant leaks- the loss rate should not exceed 1%
• Heat transfer surfaces must be clean and free of sludge and scale.
• Heat exchanger tubes – cracking, pitting, and corrosion are not desired.
• Pump bearings – repair or cleaning may be required.
Choosing the Most Effective Absorption Chiller
Even if you follow all of the aforementioned maintenance methods, the equipment will degrade, and your maintenance expenses will rise. That might be the moment to update to a more contemporary, dependable, and efficient equipment. If the system is running at part load for extended periods of time, a chiller with excellent part load efficiency may be all that is required. It is also critical to properly size the chiller. A chiller that is too large for a given application would almost certainly run at a poor efficiency. If it is subjected to such pressures for a long period of time, it may develop severe issues. The chiller upgrade/selection process should be defined by a comprehensive study of operating requirements, facility type, and timeline.
Advantages of absorption chillers
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It will also fit places where a peaceful atmosphere is a necessity — an absorption chiller is a silent, wear-free system owing to the absence of moving components — and requires little maintenance.
How to Install an Absorption Chiller
It is preferable to deal with a contractor that has expertise with complex systems such as absorption chillers. Experts can assist you in designing, building, and funding an absorption chiller system that makes financial sense for your business and has a solid, obvious route to generating a fair return on investment.
https://www.gmsthailand.com/blog/absorption-chiller/ (https://www.gmsthailand.com/blog/absorption-chiller/)
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Basic concepts of air cooled condenser, design and trending market
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Many plants are being compelled to convert existing power plants to closed-circuit cooling water systems or even dry cooling alternatives due to increasing environmental regulations and public pressure, rather than continuing to use once-through river or ocean cooling water. There just isn’t enough water available in dry areas to meet the requirements of both power plants and people.
The astute developer may also choose dry cooling early in a project since it expands plant siting choices and may substantially speed up building permit clearance because water usage concerns are eliminated. Shortening a project timeline by even six months may radically alter the economics of a project and easily offset the higher capital cost of dry cooling solutions.
Basic Concepts of Air Cooled Condenser
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- ACC is a direct dry cooling system in which steam is condensed under vacuum within air cooled finned tubes.
- The main components of an ACC are ducting (for steam transport), a finned tube heat exchanger, axial fans, motors, gear boxes, piping, and tanks (for condensate collection).
- Ambient air travels over a finned tube heat exchanger utilizing a forced draft axial fan to condense the steam.
The main component of the ACC is the finned tube heat exchanger, which comes in many varieties:
- Single Row Condenser (SRC)
- Multi Row Condenser (MRC)
The basics of air-cooled condenser design
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The direct dry cooling option condenses turbine exhaust steam within finned tubes that are externally cooled by ambient air rather than sea or river water, as in once-through water-cooled plants. There are two ways to circulate the ambient air for condensate cooling: utilize fans to move the air or take use of nature’s draft.
The natural draft system employs the well-known hyperbolic tower, which may reach heights of more than 300 feet and is equipped with a series of heat exchangers. The second, more known design option is the air-cooled condenser, which employs motor-driven fans rather than relying on the natural buoyancy of heated air. Due to the enormous scale of hyperbolic towers, natural draft is a specialized application for tiny locations. As a result, about 90% of the world’s dry-cooled power plants utilize an air-cooled condenser with mechanical draft.
The steam released from the turbine exhaust enters a steam distribution manifold situated on top of the ACC construction. The steam is then dispersed through the fin tube heat exchangers, which are placed in an A-shape arrangement in a “roof structure.” Steam condenses within the tubes due to the cooling impact of ambient air pulled across the exterior finned surface of the tubes by the fans. The fans are placed at the bottom of the A-shape structure. Condensate drains from the fin tube heat exchangers into condensate manifolds and then to a condensate tank before being piped to the traditional feed heating plant or the boiler.
An ACC works under vacuum in the same way as a normal surface condenser does. Air and other non- condensable gases enter the steam via a variety of sources, including leakage through the system border and the steam turbine. Non-condensable gases are evacuated in a separate part of the ACC known as the “secondary” section, which is linked to vacuum pumps or air ejectors that exhaust the non-condensable gases to the atmosphere.
The main variation between ACC designs from various manufacturers is in the features of the heat exchanger and its finned tubes. There are two kinds of heat exchangers: single-row and multi-row. There are many arguments for and against each concept’s benefits. In addition, the market offers three tube shapes: round, oval, and flat. The most advanced tubes are round and flat, and they work well in almost all situations.
Suppliers also differ in terms of fin form. In transitory circumstances, certain fin forms are less prone to fouling and mechanically more robust. Fins of the highest grade have a strong connection to the bare tube, ensuring a usable life expectancy similar to power plants.
The material used for the finned tubes is the last crucial design element. Aluminum fins brazed on flat bare tubes covered with aluminum, or oval galvanized finned tube bundles, are widely regarded as the two most dependable power plant technology.
If ACC is chosen, a plant site in China, as well as other places across the globe, does not need to be near a water supply. Instead, transmission lines and either gas distribution lines (for combined-cycle facilities) or rail lines may be optimized (for coal-fired plants). Solid fuel plants in China are often built near coal mines, which explains the country’s current interest in air cooling. Finally, if a lake, river, or coastal plant location is not needed, the cost of property may be lowered.
The market is trending up.
Europe had a relatively limited market for big or medium power plants during the 1960s and 1990s. It instead depended on massive coal-fired power facilities and nuclear reactors. In contrast, because of the scarcity of water, dry-cooling designs have grown in favor in the Middle East, China, South Africa, and the United States (at coal mine locations, in desert environs, or for other similar reasons). After 1990, the global market for dry cooling started to boom, and it has more than doubled in the last 13 years.
Given China’s massive electrical needs, the market for dry-cooling equipment is likely to remain busy in the near future. Reasonable growth is also anticipated in Europe, as several European Union nations rekindle their interest in controlling future water resources. In the foreseeable future, the Middle East (Emirate’s region) and India will undoubtedly become two extremely significant markets. Since the middle of 2005, the market in the United States has grown steadily.
https://www.gmsthailand.com/blog/air-cooled-condenser-is/ (https://www.gmsthailand.com/blog/air-cooled-condenser-is/)
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METROL SEA-CELL Electrochlorinator
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Overview – METROL SEA-CELL Electrochlorinator
- Prevent organism growth in your seawater systems with sodium hypochlorate
Our METROL SEA-ELL electrochlorinator is a machine which helps prevent organism growth in seawater systems. Technically, the electrochlorinator generates sodium hypochlorite by using electricity to control biofilm efficiently. Not only large organisms but also small organisms can be aggregated on the equipment. This would reduce performance and increase lifespan of the system. Therefore, if the seawater is applied in any process, the electrochlorinator should be installed to hinder biofoulant.
The METROL SEA-CELL electrochlorinator offers increased run-times and efficient protection of seawater treatment equipment. Offshore uses range from oil and gas stations and ships to floating production, storage, and offloading (FPSO) facilities, meanwhile onshore uses include industrial and refinery cooling water.
- Flexible, modular design and controls
The SEA-ELL electrochlorinator is designed for standards and specific customer’s requirements. Specially, the electrochlorinator can be used with automated chlorinator packages complete with detailed instrumentation and control features, which provide online availability and fail-safe operation.
Package ranges are also included from single-cell marine units to sophisticated units and hazardous area. Also, there are large-capacity units for power and industrial applications.
- Special Features :
- Designed to operate at 145psi (10bar), tested to 220 psi [15.2 bar]; has withstood 580 psi [40 bar] during certification trials without leaks
- Compact design reduces weight and space requirements.
- Vertical orientation facilitates removal of hydrogen byproduct of the electrolytic process
Application of METROL SEA-CELL Electrochlorinator
The SEA-CELL electrochlorinator applies “Sodium hypochlorite” via electrolysis as an oxidizing biocide for biofoulant protection.
With reliable design and auto-cleaning generator, our METROL SEA-ELL electrochlorinator has an arrangement which encloses the anode-cathode bipolar plates within a leak-proof, integral housing. Compared to other cell designs, they will use the cathode or anode as the containment device for the process fluid. Since the plates are mounted inside a substantial polypropylene container, the SEA-CELL electrochlorinator can ensure leak-free operation even during anode-cathode failure. The design is guaranteed by ATEX certified and ingress protection (IP) 65 rated. Therefore, there is no need for an additional enclosure, and help installation in harsh marine environments.
Due to self-cleaning function, our METROL SEA-CELL electrochlorinator doesn’t need to clean any acid. Instead, the cell plates are kept free of deposits and hydrogen is removed by optimizing fluid velocities.
During the process, the hypochlorite solution is in the tank under level control. After that, it will be pumped to the dosing point where the solution is released to the seawater system by multistage centrifugal dosing pumps.
Hypochlorite generation process
The hypochlorite generation process is involved with electrolysis of the sodium chloride in raw seawater. The solution flows between anodic and cathodic electrodes energized by the direct current. Then, the chemical reactions happen between the products of electrolysis.
Passing direct current through an aqueous solution of sodium chloride causes the chloride ions to migrate to the anode and sodium ions to migrate to the cathode, leading to the generation of chlorine at the anode and hydrogen plus sodium hydroxide at the cathode.
Hydroxyl ions migrate from the cathode area and react with sodium ions and chlorine dissolved in the seawater near the anode to produce sodium hypochlorite
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Project Reference
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(https://www.gmsthailand.com/wp-content/uploads/2021/09/MicrosoftTeams-image-3-800x395.jpg)
https://www.gmsthailand.com/product/metrol-sea-cell-electrochlorinator/ (https://www.gmsthailand.com/product/metrol-sea-cell-electrochlorinator/)
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Sulfate Removal System – Effective treatment of seawater for injection
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Increased technological and environmental demands are being placed on the oil and gas industry to find cost-effective methods to control scale formation apparent as a result of waterflood.
Overview – Sulfate Removal System
Prevent reservoir damage from sulfate introduction
There are two main problems that the sulfate removal system can solve. One is scale control and the other one is souring control. When sulfates run into the reservoir, the scale will be precipitated. After that, it will react with barium and strontium salts which are already in the formation.
Removing sulfate can reduce feed for existing sulfate-reducing bacteria in the formation. Hydrogen sulfide is the byproduct of bacteria’ s consumption.To avoid damaging operation and corrosion, hydrogen sulfide (H2S) should be removed because it will decrease lifespan of the equipment.
Incorporate sulfate removal into a seawater process
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After spending many years for deep understanding and experience of design and installation ,sulfate removal system has advantages beyond scales or hydrogen sulfide reduction.The removal system can be used with other technologies that we provide, such as the Polymem UF seawater ultrafiltration system. The entire process guarantee is also available rather than a guarantee for individual technologies.
ADVANTAGES
- High-quality injection water
- Avoidance of well workover
- Reduced HSE hazards
- Reduced need for biocides
- Reduced scaling in piping and equipment
- More effective squeeze treatments
- Control of bacterial well souring
- Lower operating costs
- Increased productivity
Application of Sulfate Removal System
To help solve problems from the source, sulfate removal technology is one of the advanced technologies to enable productivity and lower costs. Before injection, removing sulfate can decrease barium and strontium sulfate scaling and prevent reservoir souring.
Since intending to solve problems sustainably, Schlumberger enhances membrane separation solutions for sulfate removal. Schlumberger develops not only stand-alone but also turnkey systems for any customer’s requirements. Therefore, these solutions provide efficient technologies for
- vertical production wells
- gravel-pack wells
- dilution water in HPHT environments
- horizontal wells with subsea tiebacks
- floating production systems
- reservoir souring control.
One of sulfate reduction methods is Membrane separation. Plus, this method is very environmentally friendly. The low-sulfate seawater product is normally in the range of 40 mg/L and dependent on water temperature and other operating parameters. The percentage of product from feedwater is 75%.
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Project Reference
(https://www.gmsthailand.com/wp-content/uploads/2021/09/MicrosoftTeams-image-2-768x450.jpg)
(https://www.gmsthailand.com/wp-content/uploads/2021/09/MicrosoftTeams-image-3-800x395.jpg)
https://www.gmsthailand.com/product/sulfate-removal-system-effective-treatment-of-seawater-for-injection/ (https://www.gmsthailand.com/product/sulfate-removal-system-effective-treatment-of-seawater-for-injection/)
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NATCO ELECTRO-DYNAMIC DESALTER
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The NATCO ELECTRO-YNAMIC DESALTER electrostatic desalting technology provides multiple phases of electrostatic mixing, coalescing, and settling in a single vessel, delivering nearly 100% salt and dehydration efficiency. The technology provides two-staged desalting efficiency without the excessive capital investments or space requirements common to conventional systems.
Comprising five proven Schlumberger process technologies, the NATCO ELECTRO-DYNAMIC DESALTER technology provides the refining industry with one of the first electrostatic desalting innovations in more than a decade.
Overview – NATCO ELECTRO-DYNAMIC DESALTER
Increase operating efficiency while reducing operational expenses
- Under a variety of conditions, the NATCO ELECTRO-DYNAMIC DESALTER technology can
- Retrofit your single-stage system to two-stage performance
- Increase the levels of salt removal over any other single-vessel process
- Double the salt removal capacity of two-stage systems
- Reduce initial capital costs for new installations
- Allow higher inlet water cuts during upset conditions while maintaining specified effluent requirements
- Improve effluent water quality
- Improve operational flexibility by handling a wide range of feedstocks
- Decrease chemical consumption
- Improve mixing efficiency
- Reduce washwater requirements
- Require less space
- Provie improved dehydration capabilities.
Application of NATCO ELECTRO-DYNAMIC DESALTER
Five steps to successful desalting
1. NATCO DUAL POLARITY electrostatic treater—applies a high-gradient, sustained DC field between pairs of electrodes while maintaining an AC field between the electrodes and oil/water interface
- Results: significant improvements compared with AC dehydration
2. Composite electrodes—obtains a progressive electrical field
- Results: coalescence of the smallest of water droplets while eliminating sustained arcing due to highly conductive emulsions
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3. LRC-II smart interface—regulates the flow of electrical current and provides self-adjusting electrical power levels for optimized electrostatic coalescence
- Results: optimal salt removal over a wide range of feed stock materials
4. Countercurrent dilution water process—increases contact between dilution water, produced water, and particulate
- Results: improved crude desalting using less washwater
5. Electrodynamic mixing process—provides multistage contact
- Results: near-100% mixing efficiencies while enabling reduced demulsifier chemical consumption
https://www.gmsthailand.com/product/natco-electro-dynamic-desalter/ (https://www.gmsthailand.com/product/natco-electro-dynamic-desalter/)
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NATCO DUAL POLARITY Electrostatic treater
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The NATCO DUAL POLARITY Electrostatic treater employs AC and DC fields and incorporates a power units that have become an industry standard for reliability.
Overview – NATCO DUAL POLARITY Electrostatic treater
- More efficient dehydration and desalting at lower operating temperatures
The NATCO DUAL POLARITY electrostatic treater outperforms both mechanical and AC electrostatic treaters in upstream crude oil dehydration and desalting applications and as a first-step desalter in refining operations.
Using both AC and DC fields from a power unit that has become the benchmark for reliability in the industry, the NATCO DUAL POLARITY treater more efficiently coalesces water droplets, enabling it to run at higher throughputs than conventional electrostatic treaters. Other internal components, such as composite electrodes that resist solids loading and a high-flow distributor that improves vessel hydraulics, also support increased throughput while reducing maintenance and opex.
- Improved performance
NATCO LRC-II smart interface, an optional load-responsive controller, enhances emulsion resolution via voltage modulation. This enables you to operate at the optimal voltage for a variety of crude feedstocks while managing upsets more rapidly and effectively.
- Cost-effective treatment
The NATCO DUAL POLARITY treater handles a wider range of inlet water cut and provides higher treating capacities at lower operating temperatures, reducing capex and opex. The treater requires less washwater than an AC desalter because of improved mixing from electrophoretic movement of the water droplets in the electrostatic field. The treater can be delivered as a heater treater, providing heating and dehydration in a single vessel and eliminating the need for externally heated heat transfer fluid.
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- Using AC and DC fields for more effective removal of formation water from crude oil
The NATCO DUAL POLARITY treater uses the extremely efficient HiFlo spreader to evenly distribute the incoming wet crude and create a uniform vertical flow upward through the treater. This method eliminates grid bypass and local recirculation areas.
The bulk water and larger water drops are coalesced and separated by gravity in the weaker AC field that exists between the grounded water phase and the electrodes. The stronger DC field between the electrodes causes rapid movement of the remaining small water droplets through electrophoretic attraction, causing the water droplets to collide, coalesce, and settle by gravity.
In desalter applications, washwater is added upstream of the mixing valve in the treater’s inlet piping. Together with the electrophoretic movement of the water droplets, this provides a very high degree of mixing with the brine. Superior mixing and improved dehydration make the NATCO DUAL POLARITY treater much more effective than AC desalters of similar size.
Application of NATCO DUAL POLARITY Electrostatic treater
The treater’s dual-olarity design enables it to split the voltage with rectifiers into positive and negative components. Pairs of vertical electrodes are charged in opposition. The oil-water emulsion from the distributor enters the DC field between electrodes, and the water droplets will accept the polarity of the closest electrode. Once the emulsified water droplets approach an electrode plate, they accept the charge of that plate. The water droplets are moved by electrophoretic force toward the electrode of opposite polarity, causing head-on collisions and coalescence. When the droplets are large enough, gravity will overcome the DC field, and the droplets will separate by gravity into the water phase.
https://www.gmsthailand.com/product/natco-dual-polarity-electrostatic-treater/ (https://www.gmsthailand.com/product/natco-dual-polarity-electrostatic-treater/)
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NATCO DUAL FREQUENCY Electrostatic treater
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The patented NATCO DUAL FREQUENCY electrostatic treater uses a proprietary process controller,NATCO LRC-lI smart interface,and three-phase power unit to produce a customized electrostatic field that can be readily optimixed for any crude oil.The technology provides a nearly 100% process improvement compared with conventional electrostatic technology
Overview – NATCO DUAL FREQUENCY Electrostatic treater
- Dehydrate and desalt upstream crude oil processes
The NATCO DUAL FREQUENCY electrostatic treater uses both AC and DC power to provide significant process improvement, often more than 100%, over conventional AC electrostatic technologies. It uses our proprietary load-responsive controller—the NATCO LRC-II smart interface—and a three-phase high-requency power unit to generate a customized electrostatic field that can be optimized for any crude oil.
The treater can be delivered as a heater treater, providing heating and dehydration in a single vessel and eliminating the need for an externally heated heat transfer fluid. It can also be provided as a degassing treater, eliminating the need for a separate degasser.
- Treat cost effectively
The NATCO DUAL FREQUENCY treater reduces capex and opex through its higher treatment capacity, higher tolerance to wet crudes, and increased dehydration performance. Moreover, it allows reduced demulsifier dosage, less washwater usage, and a lower operating temperature.
- Improve performance with real-time control
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The LRC-lI interface improves emulsion resolution via voltage modulation, enabling operation at the optimal voltage for multiple crude feedstocks, while managing upsets more rapidly and effectively. Parameter setup in the treater power unit can be updated from the LRC-II interface in real time while the unit is operating.
The HiFlo spreader improves vessel hydraulics and enhances performance to support higher process capacity.
- A two-pronged approach to remove formation water from crude oil
The NATCO DUAL FREQUENCY treater uses the extremely efficient HiFlo spreader to evenly distribute the incoming wet crude and create a uniform vertical flow upward through the treater. This method eliminates grid bypass and local recirculation areas.
The bulk water and larger water drops are coalesced and separated by gravity in the weaker AC field that exists between the grounded water phase and the electrodes. The stronger DC field between the electrodes causes rapid movement of the remaining small water droplets through electrophoretic attraction, causing the water droplets to collide, coalesce, grow, and separate by gravity.
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In desalter applications, washwater is added upstream of the mixing valve in the treater’s inlet piping. Together with the electrophoretic movement of the water droplets, this provides a very high degree of mixing with the brine. Superior mixing and improved dehydration make the NATCO DUAL FREQUENCY treater much more effective than conventional AC desalters of similar size.
Use of a high base frequency for the electrostatic field provides stronger electrostatic forces. Low-frequency amplitude modulation of the field improves conditions for water droplet coalescence, further enhancing dehydration and desalting efficiency.
We also retrofit existing AC treaters to improve their capacity and enable lower operating temperatures and emulsifier dosages.
- Boost your electrostatic treater
A high-efficiency power unit upgrades NATCO DUAL FREQUENCY units to improve facility opex by increasing treater reliability and simplifying maintenance.
With the new unit installed,
- treaters operate at higher temperatures and with wider power variations.
- new sensors monitor trends in the health of key components, enabling warnings before as well as during an upset condition.
- unit maintenance can be performed without removing it or draining the oil.
- an AgoraGateway ruggedized edge computing device enables optional remote, real-time health monitoring and life-of-asset collaboration.
Application of NATCO DUAL FREQUENCY Electrostatic treater
Three primary components are packaged in a single oil-filled enclosure. First is the power electronics, designed to produce a variable amplitude and variable frequency voltage field. For many field installations, this is a key feature of the technology, as it enables an optimization of the applied voltage. Second, the medium-frequency power unit provides for the increased secondary voltage known to promote effective coalescence. Third, the secondary voltage is rectified to produce electrophoretic movements of the water droplets, which improves both dehydration and desalting. A DC field is created between the electrodes, enabling droplet motion and efficient coalescence. Simultaneously, an AC field is created between the electrodes and the grounded water phase, enabling bulk water removal in the weaker AC field.
Traditional AC technologies typically experience rapid voltage decay or arcing when operated in very wet crude oil service. This decay reduces the effectiveness of the dehydration process by reducing the voltage lower than what is required for effective dehydration.
By applying a higher-frequency electrostatic field, the treater reduces this voltage decay and enables effective dehydration, thus overcoming the voltage decay experienced with conventional 50/60-Hz transformers. The specific oil and water properties, operating temperature, and formation solids all combine to create a unique emulsion that often can be very difficult to resolve. To break the emulsion, the patented NATCO DUAL FREQUENCY treater uses a microprocessor-based system that includes the LRC-II smart interface and defines the pattern and amplitude of the voltages that are applied to the electrodes. The proprietary LRC-II smart interface enables selection of the shape and amplitude of the voltage waveform to optimize coalescence of the water droplets, leading to an effective resolution of the emulsion and low water content in the treated crude.
https://www.gmsthailand.com/product/natco-dual-frequency-electrostatic-treater/ (https://www.gmsthailand.com/product/natco-dual-frequency-electrostatic-treater/)
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Advanced Media Polisher/ Oil-in-water polishing filters
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The advanced media polisher oil-free water technology instantly and permanentsly removes or reduces oil ,suspended solids and highly emulsified oils from water. Built on this technology, the advanced Oil-in-water polishing filters provide enhanced stand-by protection against upset conditions and underperformance of conventional trearment equipment upstream for polisher. THe filter technology is a simple cartridge filtration system with a patented thin film polymer deposited on filter fibers that is a surfacd specific for hydrocarbons.
Overview – Advanced Media Polisher/ Oil-in-water polishing filters
- Achieve discharge levels under 1 ppm, even at high flow rates
Our advanced media polishers or Oil-in-water polishing filters provide enhanced standby protection against upset conditions and underperformance of conventional upstream treatment equipment. The polisher filter consists of a simple cartridge filtration system with a patented thin-film polymer, surface-specific for hydrocarbons, deposited on filter fibers.
These filters provide a higher flow capacity and smaller footprint than conventional tertiary treatment technology. They are used at many sites across the oil and gas industry for final treatment of water before discharge to offshore, nearshore, or inland bodies of water.
- Selective polishing compatible with CEOR that still treats droplets down to <1 um
The advanced media polisher also removes oil in the presences of water-soluble polymers used in chemical enhanced oil recovery (CEOR) while still treating down to a droplet size that ensures no hydrocarbon sheen from the overboard discharge of produced water.
- Special features:
- Removes free, dispersed, and emulsified oil down to <1-um droplet size
- Occupies a small footprint in comparison with conventional technologies
- Treats emulsions without the use of chemicals
Application of Advanced Media Polisher/ Oil-in-water polishing filters
Instant polishing with thin-film coated media filtration
The polishing media removes oil and grease without desorption and with minimal to no saturation with water. Advanced media polishing filters are normally used to target oil droplets smaller than upstream equipment can handle (typically less than 10 um in diameter) with high efficiency.
Water passes through a standard series of three skid-mounted vessels housing consumable cartridge filters. Sized according to desired flow rate, each vessel can hold up to 210 filters that are 40 in long and have a diameter of 2.5 in. As the process stream passes through each vessel, oil droplets contact the filter surface and are instantly and permanently removed from the stream.
https://www.gmsthailand.com/product/oil-in-water-polishing-filters/ (https://www.gmsthailand.com/product/oil-in-water-polishing-filters/)
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Advanced Regenerative Water Treatment Media
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Advanced Regenerative Water Treatment Media instantly and permanently removes oil, suspended solids,and highly emulsified oils from water. Built on this technology, the advanced media is a proprietary back-washable system used in oily wastewater streams and produced and process water.Coated with proprietary technology patented polymer,the regenerative media provides an economically sustainably treatment for the removal of oils and suspended solids.
Overview – Advanced Regenerative Water Treatment Media
- 95% single-pass efficiency without chemicals
Advanced regenerative water treatment media is a proprietary, backwashable media used for produced water, oily wastewater streams, and process water. Coated with a patented polymer, the media economically removes oils and suspended solids down to 5 um with 95% single-pass effectiveness and without the use of chemicals.
This media can function as a primary or secondary treatment option for oil and solids removal. Influent water quality, discharge requirements, and the end use of the treated water dictate the treatment system design.
- Process and cost savings
For chemical enhanced oil recovery (CEOR) applications, polymer- and chemical-laden water that has been treated with regenerative water treatment media can be recycled for reuse in the injection field and, in the case of polymer, with no viscosity loss across the system. Little if any of the the water-soluble enhanced oil recovery (EOR) products are caught while the media removes oils and solids. In thermal EOR, trapping the oil and solids before sending the produced water to a softener generates process and cost savings.
- Special features:
- Removes oil, solids, and oil-coated solids down to 5 um in a single step, without additional chemicals for water separation
- Treats CEOR produced water from polymer and alkaline-surfactant-polymer (ASP) floods without absorbing the polymer
- Has a long life cycle and low operating cost
- Prevents process upsets and excursions with minimal impact on performance
Application of Advanced Regenerative Water Treatment Media
Simple backwashing process
Advanced regenerative water treatment media is used in conventional deep-bedded media filter vessels and the oil it traps is recovered through typical backwash techniques. The backwash removes contaminants by reversing the flow direction and fluidizing the packed bed, loosening the media and releasing both solids and oil droplets from the media.
When the proprietary regenerative water treatment media is backwashed, the effluent is typically captured in a static separation vessel. Free oil and solids are easily decanted from the surface for disposal or recovery. The remaining supernatant is used to backwash the filters during the next backwash cycle. Backwash is either manual or automatic depending on the system deployed.
https://www.gmsthailand.com/product/advanced-regenerative-water-treatment-media/ (https://www.gmsthailand.com/product/advanced-regenerative-water-treatment-media/)
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CYNARA Acid Gas Removal Membrane Systems
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From the world’s first commercial CO2 membrane plant for CO2 recovery in EOR appplications to the world’s largest CO2 membrane plant for natural gas cleanup. Schlumberger continues to lead the industry with state-of-the-art CYNARA acid gas removal membrane systems
Overview – CYNARA Acid Gas Removal Membrane Systems
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- CO2 and H2S removal with field-proven 99% operational uptime
CYNARA acid gas removal membrane systems efficiently and selectively permeate acid gases to separate them from produced gas streams that contain 5- to 95-mol% acid gas.
These systems are ideal for stand-alone bulk acid gas removal and the treatment of produced gas to meet pipeline transmission and natural gas heating specifications. They can provide permeate streams of more than 95% pure CO2 for enhanced oil recovery (EOR) injection applications. Used in a hybrid acid gas treatment train, they provide bulk separation of produced gas streams that are subsequently treated by an amine system or other separation technologies.
- Compact design eliminates liquid chemicals and improves logistics
The compact footprint of the membrane systems and their largely self-contained functionality make them well suited for offshore applications. There are no moving parts or chemical requirements because the systems work on the principle of diffusion and solubility-based separation.
In addition to eliminating the weight of liquid chemicals and the need for liquid recirculation equipment and associated maintenance, CYNARA systems eliminate the logistics associated with the transportation and storage of liquid amine chemicals onshore and offshore. The need to superheat gas streams containing >40% CO2 and related costs are also minimized because the membranes can efficiently handle condensing hydrocarbons.
- Options to optimize performance for different acid gas concentrations
Three membrane-based acid gas removal options are available.
– CYNARA CLASSIC high-concentration acid gas removal membrane removes the highest levels of acid gas from produced gas streams.
– CYNARA PN-1 dual-zoned acid gas removal membrane permeates the highest concentrations of inlet acid gas in Zone 1, directing lower concentrations of acid gas into Zone 2, and optimizing the treatment of produced gas streams with irregular levels of CO2 and H2S.]
– CYNARA SEMPLE high-pressure, low-concentration acid gas removal membrane system is designed to treat high-pressure produced gas streams that have acid gas concentrations of less than 30%. This standardized, preengineered plug-and-play assembly, with its single-ended membrane configuration, enables smaller vessel housings with greater membrane surface area, lower equipment weight, and more compact skid size.
Application of CYNARA Acid Gas Removal Membrane Systems
Hollow-fiber membrane maximizes acid gas separation
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CYNARA systems use tubular membrane elements that consist of a central steel tube surrounded by a sheet of asymmetric, hollow fibers made from cellulose triacetate polymer. Millions of these hollow fibers are combined to make a single element, which is housed in a case.
As the inlet natural gas stream is drawn through the membrane, small molecules such as CO2 and H2S in the gas stream permeate into the fibers much faster than the larger, more complex natural gas components (e.g., methane and higher hydrocarbons). The smaller molecules flow around the fibers into the central core. A low-pressure CO2-rich stream flows through the tube sheets and exits the element at both ends. The high-pressure natural gas product stream, with the bulk of the acid gas removed, exits through the core steel tube.
https://www.gmsthailand.com/product/cynara-acid-gas-removal-membrane-system/ (https://www.gmsthailand.com/product/cynara-acid-gas-removal-membrane-system/)
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Early Production Systems
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Accelerate the time to first oil and gas
Begin production early while full field development is being planned and permanent facilities are being built. Early-production systems help operators bring their new discoveries onstream fast. Schlumberger has designed and installed modular, fit-for-purpose systems worldwide for more than 30 years and to date has completed approximately 70 projects.
Early production systems and fast-track schedules can create an early cash flow for operators with only a minimum cash outlay. They also provide real-time production data for appraising reservoir performance before more-expensive long-term facilities are installed. In addition, early production systems are ideal for small reserves that would be financially risky or uneconomical to produce with a permanent production facility.
Production services
An extensive range of production services is available, based on the early production system business model selected:
- Fast-track early production and interim plants and systems
- Hydrocarbon liquids recovery and dewpoint control plants
- Gas storage leaching facilities
- CO2 and H2S removal
- Multiphase pumping
- Optimization of existing production facilities *All necessary support systems (power generation, controls, monitoring and detection, and operation camps)
Flexible business models
Schlumberger offers a variety of commercial business models for early production systems that afford customers the flexibility to maximize their return on investment:
- Build—Own—Operate (equipment rental plus operation)
- Build—Own—Operate—Transfer (equipment rental plus operation with the option to purchase)'
https://www.gmsthailand.com/product/early-production-systems/ (https://www.gmsthailand.com/product/early-production-systems/)
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MYCELX Polisher Oil-In-Water Polishing Filter
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MYCELX Polisher oil-in-water polishing filters provide enhanced standby protection against upset conditions and underperformance of conventional upstream treatment equipment.
Achieve oil-in-water discharge levels <1 ppm even at high flow rates
MYCELX Polisher oil-in-water polishing filters provide enhanced standby protection against upset conditions and underperformance of conventional upstream treatment equipment. The MYCELX Polisher filter technology consists of a simple cartridge filtration system with a patented thin film polymer deposited on filter fibers; the polymer is surface specific for hydrocarbons.
These filters provide a higher flow capacity and smaller footprint than conventional tertiary treatment technology. They are used on many sites across the oil and gas industry for final treatment of water before discharge to offshore, nearshore, or inland bodies of water.
Advantages
- Removes free, dispersed, and emulsified oil down to <1-um droplet size
- Occupies a small footprint in comparison with conventional technologies
- Treats emulsions without the use of chemicals
- Ensures no hydrocarbon sheen for overboard discharge of produced water
- Removes oil in the presence of water-soluble polymers used in chemical enhanced oil recovery (CEOR)
https://www.gmsthailand.com/product/mycelx-polisher-oil-in-water-polishing-filter/ (https://www.gmsthailand.com/product/mycelx-polisher-oil-in-water-polishing-filter/)
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Displacer Type Liquid Level Switches
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Displacer Type Liquid Level Switches offer the industrial user a wide choice of alarm and control configurations. Every unit utilizes a simple buoyancy principle and is well suited for simple or complex applications, such as foaming or surging liquids or agitated fluids, and usually costs less than other types of level switches.
Technology of Displacer Type Liquid Level Switches
Displacer Type Liquid Level Switches are based upon simple buoyancy, whereby a spring is loaded with weighted displacers which are heavier than the liquid. Immersion of the displacers in the liquid results in buoyancy force change, which moves the spring upward. Since the spring moves only when the level moves on a displacer, spring movement is always a small fractionof the level travel between displacers. A magnetic sleeve is connected to the spring and operates within a non-magnetic barrier tube. Springmovement causes the magnetic sleeve to attract a pivoted magnet ƒ, actuating a switch mechanism ≈ located outside the barrier tube. Built-in limit stops prevent over stroking of the spring, under level surge conditions.
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Features of Displacer Type Liquid Level Switches
- Narrow or wide level ranges achieved through multiple switch mechanism capability.
- Up to 4 set points and 3 switches.
- Displacers adjustable at any point along the suspension cable.
- 10 feet (3 meters) suspension cable standard.
- Anti-surge design eliminates the possibility of switch shortcycling.
- Flanged or threaded mounting available.
- Easy installation.
- Field adjustable set point and switch differential.
- NACE models.
- Floating rooftop models.
- Proof-er® ground check.
- Choice of displacers: Porcelain, 316 Stainless steel, Karbate, Brass.
- Choice of switch mechanisms: Dry contact,Pneumatic, Hermetically sealed.
- Available housings: NEMA 1, carbon steel for pneumatics; TYPE 4X/7/9, Class I, Div. 1, Groups C & D, polymer coated aluminum; TYPE 4X/7/9,Class I, Div. 1, Group B, polymer coated aluminum.
Applications of Displacer Type Liquid Level Switches
- Foaming or surging liquids
- Agitated fluids
- Sewage handling
- Dirty liquids
- Paints
- Varnishes
- Heavy oils
- Liquids with solids
https://www.gmsthailand.com/product/displacer-type-liquid-level-switches/ (https://www.gmsthailand.com/product/displacer-type-liquid-level-switches/)
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Pneumatic Modulevel Liquid level control
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Pneumatic Modulevel® Liquid level controls are displacement actuatedlevel sensors. They provide output signals in direct proportion to changes in liquid level.Simple, modular design and proven magnetic coupling make Modulevel controls versatile, highly stable, vibration resistant and adaptable to extremes of temperature and pressure.
Principle OF Pneumatic Modulevel Liquid level control
The key elements of the Pneumatic Modulevel Liquid level control are the magnetic coupling, which allows the controller to be mechanically isolated from the sealed sensing unit; the range spring, which dampens the action of the displacer, and the control head, which provides a modulated pneumatic signal in direct proportion to the input from the vertical motion of the displacer.As the liquid level in the vessel increases or decreases, the buoyant displacer rises or falls.This motion, dampened by the action of the range spring to prevent response to the rapid fluctuations of turbulence, is mechanically coupled to an attractor ball, within an enclosed tube. A magnet encircling the tube follows the attractor ball, transferring the motion to a rotating cam,which in turn operates a flapper against a nozzle which increases or decreases the pressure within the pneumatic relay. The output pressure signal can be used in a variety of ways to operate a control valve or signal to alarms, indicators, process controls or other devices. With optional integral control, the pilot nozzle proportional signal is conditioned through an additional metering valve system, which will eliminate offset from the desired control point.
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Features of Pneumatic Modulevel Liquid level control
- Standard models handle service temperatures from -100°C to +370°C (-150°F to +700°F) and pressure to 294 bar (4265 PSIG).
- Stable output signal is unaffected by surface turbulence.Prevents control valve “hunting” and extends valve life.
- Controller head may be removed and bench calibrated without dismantling or even depressurizing the tank.
- Accurate output signal provided over a wide specific gravity range.
- 316 SS displacer and trim.
- Easily field calibrated without moving tank liquid level, for reduced installation time and cost.
- Controller head rotates 360°, simplifies pneumatic piping hookup.
- Pilot relay provides a 4 to 1 amplification of pilot pressure signal to speed valve response.
- Built-in visual level indicator is independent of air supply.
- Optional pneumatic to current interface transducer for use in electronic control applications.
- Optional proportional plus integral control.
- Optional differential gap (on-off) control.
- Optional Hi-Lo electronic alarm signal provides inexpensive backup alarm.
Applications of Pneumatic Modulevel Liquid level control
Pneumatic Modulevel® liquid level controls are widely used in utility power generation, chemical and petroleum processing operations, such as:
- Steam generator feedwater
- heater regulation
- Fractionating column level transmitter
- Ethanolamine level transmitter
- Vent gas scrubber level control
- Drip pot condensate level control
- Flash tank level transmitter
https://www.gmsthailand.com/product/pneumatic-modulevel-liquid-level-control/ (https://www.gmsthailand.com/product/pneumatic-modulevel-liquid-level-control/)
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Boiler and Water Column Liquid Level Switch
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C24, C25, Boiler and Water Column Liquid Level Switch are single or multi-switch units that offer versatility and reliable operation in a variety of applications. Available with up to three switch mechanisms for levelalarm, control, and shutdown functions, the boiler and water column controls are designed for use in steam boiler applications while the Models C24 & C25 are forgeneral industrial use.
Technology of Boiler and Water Column Liquid Level Switch
Boiler and Water Column Liquid Level Switch uses a long-lasting magnet. A permanent magnet➀is attached to a pivoted switch actuator and adjustment screw ➁. As the float ➂ rises following the liquid level, it raises the attraction sleeve ➃ into the field of the magnet,which then snaps against the non-magnetic enclosing tube ➄, actuating the switch ≈. The enclosing tube provides a static pressure boundary between the switch mechanism and the process.On a falling level, an inconel spring retracts the magnet, deactivating the switch.
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Features of Boiler and Water Column Liquid Level Switch
- Easy inspection of float chamber through removable head
- Cast iron or fabricated steel float chambers
- 316 and 316L stainless steel floats
- Brass chamber liner standard in B24, B25 and W25 models
- Right or left hand water column mounting
- Try cock tappings and sight glass tappings available
- Process temperatures up to +1000° F (+538° C)
- Multiple switch capability
- Working steam pressure to 600 pounds
- Choice of switch mechanisms: Pneumatic Hermetically sealed Dry contact
- Choice of switch mechanism enclosures: NEMA 1 carbon steel for pneumatic TYPE 4X/7/9 Class I, Div. 1, Groups C & D, polymer coated aluminum TYPE 4X/7/9 Class I, Div. 1, Group B, polymer coated aluminum
- Optional high temperature insulation available. See bulletin 41-106.
Application of Boiler and Water Column Liquid Level Switch
- OCondensate receiver control
- OFlash tank high level alarm
- OWater tube boiler low water cutoff
- OBoiler steam chest high level alarm
- OBoiler feedwater pump control
- ODay tanks
- OBoiler low water cutoff
- OHolding tanks
https://www.gmsthailand.com/product/boiler-and-water-column-liquid-level-switch/ (https://www.gmsthailand.com/product/boiler-and-water-column-liquid-level-switch/)
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Echotel Model 910 Ultrasonic Level Switch
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Echotel Model 910 Level Switches utilize ultrasonic contact technology for measuring level in clean liquid applications. The dual conduit electronics houses an 8-amp DPDT gold flash relay that is field selectable for high or low level fail-safe applications. There are no moving parts that come in contact with the medium. The Echotel Model 910 is an integrally mounted system, comprised of surface mount electronics and a 316 stainless steel transducer. Hazardous area location approvals are available from FM, CSA, and ATEX.
Technology of Echotel Model 910 Ultrasonic Level Switch
The Model 910 Level Switch uses ultrasonic energy to detect the presence or absence of liquid in a 316 stainless steel tip sensitive transducer gap. The basic principle behind ultrasonic contact technology is that high-frequency sound waves are easily transmitted across a transducer gap in the presence of a liquid medium, but are severely attenuated when the gap is dry. The Model 910 uses an ultrasonic frequency of 3 MHz to perform this liquid level measurement in a wide variety of process media and application conditions. The transducer uses a pair of piezoelectric crystals that are encapsulated in epoxy at the tip of the transducer. The crystals are made of a ceramic material, such as lead zirconate. The transmit crystal converts an electrical signal from the Model 910 electronics into an ultrasonic signal. When liquid is present in the gap, the receive crystal is able to sense the ultrasonic signal from the transmit crystal and convert it back to an electrical signal. This signal is sent to the electronics to indicate the presence of liquid in the transducer gap. When there is no liquid present, the ultrasonic signal is attenuated, and the receive crystal is not able to sense the sound waves from the transmit crystal.
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Features of Echotel Model 910 Ultrasonic Level Switch
- Measures level within 0.25″ (6 mm) from the end of the tip-sensitive transducer gap
- 8-amp DPDT gold flash or 5-amp DPDT hermetically sealed relay
- Surface mount conformal coated electronics
- FM, CSA, and ATEX approved for hazardous locations
- Variety of mounting options including NPT and BSP threaded, flanges and hygienic connections
- No calibration required
- 316 stainless steel transducer
- Mounted horizontally or vertically
- Compact dual conduit cast aluminum electronics housing
- Two-year product warranty
Applications of Echotel Model 910 Ultrasonic Level Switch
- Seal Pot Level
- Low Level Alarm
- High Level Alarm
- OEM/Skid Packages
- Pump Protection
https://www.gmsthailand.com/product/echotel-model-910-ultrasonic-level-switch/ (https://www.gmsthailand.com/product/echotel-model-910-ultrasonic-level-switch/)
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Echotel Model 940/941 Ultrasonic Level Switch
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Echotel Model 940/941 Ultrasonic Level Switch is compact integral units that utilize pulsed signal technology to perform high or low level measurement in a wide variety of liquid applications. These switches feature a 316 stainless steel tip-sensitive transducer that is offered in a variety of NPT, flanged, and hygienic process connections. The compact electronics are completely encapsulated just above the process fitting.The Magnetrol® Model 940 offers a 1-amp SPDT relay output. The Model 941 has a mA current shift output.
Technology of Echotel Model 940/941 Ultrasonic Level Switch
Ultrasonic energy detects the presence or absence of liquid in a tip sensitive transducer gap. The principle behind contact ultrasonic technology is that high frequency sound waves are easily transmitted across a transducer gap in the presence of liquid, but are attenuated when the gap is dry.The transducer uses a pair of piezoelectric crystals that are encapsulated in epoxy at the tip of the transducer. The crystals are made of a ceramic material that vibrates at a given frequency when subjected to an applied voltage. The transmit crystal converts the applied voltage from the electronics into an ultrasonic signal. When liquid is present in the gap, the receive crystal is able to sense the ultrasonic signal from the transmit crystal and convert it back to an electrical signal. This signal is sent to the electronics to indicate the presence of liquid in the transducer gap. When there is no liquid present, the ultrasonic signal is attenuated and is not detected by the receive crystal.
(https://www.gmsthailand.com/wp-content/uploads/2021/10/Ultrasonic-Level-Switch-2-510x507.jpg)
Features of Echotel Model 940/941 Ultrasonic Level Switch
- Pulsed electronics for excellent performance in difficult process conditions and superior immunity from sources of electromagnetic noise
- Tip-sensitive transducer gap provides reliable operation by draining viscous liquids and shedding foam in turbulent applications
- Safety Integrity Level (SIL) data (FMEDA analysis) is available. Model 940 is suitable for SIL 2 loops.Model 941 is suitable for SIL 1 loops.
- Extremely compact unit is easily installed in areaswhere access space is limited
- 1-amp SPDT relay output (940), or mA current shift (941) output
- No calibration required
(https://www.gmsthailand.com/wp-content/uploads/2021/10/Ultrasonic-Level-Switch-1.jpg)
Applications of Echotel Model 940/941 Ultrasonic Level Switch
The Model 940/941 can be applied in a wide variety of high or low liquid level applications, pump protection,and fill line monitoring as shown in the diagram at the left. These compact units can also be installed in the interstitial space between two tank walls for fluid leak detection.Small size and simplicity of installation make these units ideal for OEM skids as a low cost, yet high performance level measurement solution. They are also the perfect replacement for older floats, conductivity switches, and tuning forks.
https://www.gmsthailand.com/product/echotel-model-940-941-ultrasonic-level-switch/ (https://www.gmsthailand.com/product/echotel-model-940-941-ultrasonic-level-switch/)
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Echotel Model 335 Non-Contact Ultrasonic Transmitter
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Echotel Model 335 is a high performance, non-contact ultrasonic transmitter for liquid level, volume, and open channel flow measurement. The extremely powerful and flexible software incorporated in the Echotel 335 results in virtually unsurpassed measurement performance. Advanced digital signal processing enables the 335 to perform in applications involving in-tank obstructions, light foam and agitation.
Technology of Echotel Model 335 Non-Contact Ultrasonic Transmitter
Non-contact ultrasonic level technology is a proven method for accurate liquid level measurement. This technology features the ability to measure the level or volume of the fluid without making physical contact withthe material. This is especially important in applications containing corrosive materials, suspended solids or coating media.The level measurement is made by emitting an ultrasonic pulse from the transducer and measuring the time required for the echo to reflect from the liquid surface and return to the transducer. The powerful electronics measure the time of the round trip pulse and, by knowing the speed of sound, calculates the distance. Since speed of sound is temperature dependent, the transducer also measures the temperature in the vessel to provide compensation for changing temperature. By inputting the type and geometry of the vessel, the intelligent electronics can calculate the liquid volume in the vessel. In a similar operation, the Model 335 can perform open channel flow measurement by converting the level reading into units of volume per time. Common tank shapes, flumes, and weirs are stored in the 335 software. A 32-point linearization table is also available for unusual tanks or primary flow elements.
(https://www.gmsthailand.com/wp-content/uploads/2021/10/Non-Contact-Ultrasonic-Transmitter-1.jpg)
Features of Echotel Model 335 Non-Contact Ultrasonic Transmitter
- Custom graphics LCD display module with operational status icons.
- Advanced digital signal processing assures reliable measurement in difficult applications
- Dual function bar graph displays echo signal strength or tank level
- 50 kHz transducer with 26 ft (8 meter) range
- Narrow, 7-degree beam angle for excellent focus
- 4–20 mA output and SPDT relay for level control, alarm, diagnostics or remote flow totalization
- Fixed target suppression to eliminate interference from in-tank obstructions
- Common tank shapes and 32-point linearization table for volume calculations
- Extensive support of flume and weir calculations for open channel flow
- Two totalizers for flow, one resettable, and one non-resettable
- Temperature compensation over full range of transducer
Applications of Echotel Model 335 Non-Contact Ultrasonic Transmitter
- Sump, well, tank and open channel measurement
- Water and wastewater treatment facilities
- General industrial applications
- Chemical storage tanks
- Vessels with highly viscous media
- Paint, ink and solvent tanks
- Food and beverage vessels
- Batch and day tanks
https://www.gmsthailand.com/product/echotel-model-335-non-contact-ultrasonic-transmitter/ (https://www.gmsthailand.com/product/echotel-model-335-non-contact-ultrasonic-transmitter/)
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Eclipse Model 706 Wave Radar Level Transmitter
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The Eclipse Model 706 Transmitter is loop-powered, 24 VDC level transmitter that is based upon the proven and accepted technology of Guided Wave Radar
Encompassing a number of significant engineering accomplishments, the Eclipse Model 706 Transmitter is designed to provide measurement performance well beyond that of many of the more traditional technologies.
Utilizing patented “diode switching” technology, along with the most comprehensive probe offering on the market, this single transmitter can be used in a wide variety of applications ranging from very light hydrocarbons to water-based media.The innovative angled, dual compartment enclosure is now a common sight in the industry. This enclosure, first brought to the industry by Magnetrol® in 1998, is angled to maximize ease of wiring, configuration, and viewing of the versatile graphic LCD display.
One universal Model 706 transmitter can be used and interchanged with all probe types, and offers enhanced reliability as it is certified for use in critical SIL 2 hardware safety loops. With the use of a unique adapter, the model706 transmitter can even operate with older Model 705 probes.The ECLIPSE Model 706 supports both the FDT/DTM and Enhanced DD (EDDL) standards, which allow viewing of valuable configuration and diagnostic information such as the echo curve in tools such as PACTware ™, AMS Device Manager, and various HART® Field Communicators
Technology of Eclipse Model 706 Wave Radar Level Transmitter
PRINCIPLE OF OPERATION
ECLIPSE Guided Wave Radar is based upon the technology of TDR (Time Domain Reflectometry). TDR utilizes pulses of electromagnetic energy transmitted down a wave guide (probe). When a pulse reaches a surface that has a higher dielectric constant than the air (εr = 1) in which it is traveling, a portion of the pulse is reflected. The transit time of the pulse is then measured via high speed timing circuitry that provides an accurate measure of the liquid (or solids) level. The amplitude of the reflection depends on the dielectric constant of the product. The higher thedielectric constant, the larger is the reflection.
(https://www.gmsthailand.com/wp-content/uploads/2021/10/Eclipse-Model-706-overall.jpg)
INTERFACE MEASUREMENT
The ECLIPSE Model 706 is capable of measuring both an upper liquid level and an interface liquid level. As only a portion of the pulse is reflected from a low dielectric upper surface, some of the transmitted energy continues down the GWR probe through the upper liquid. The remaining initial pulse is again reflected when it reaches the higher dielectric lower liquid. It is required that the upper liquid has a dielectric constant less than 10, and the lower liquid has a dielectric constant greater than 15. A typical interface application would be oil over water, with the upper layer of oil being non-conductive (εr ≈ 2.0), and the lower layer of water being very conductive (εr ≈ 80). The thickness of the upper layer could be as small as 2″ (50 mm) while the maximum upper layer is limited to the length of the GWR probe.
(https://www.gmsthailand.com/wp-content/uploads/2021/10/Eclipse-Model-706-interface-1.jpg)
Features of Eclipse Model 706 Wave Radar Level Transmitter
- Multivariable, two-wire, 24 VDC loop-powered transmitter for level, interface, volume, or flow.
- Unique adapter allows operation with Model 705 probes
- Diode switching technology offers best-in-class signal strength and signal-to noise ratio (SNR) resulting in enhanced capability in difficult low dielectric applications.
- Level measurement not affected by changing media characteristics.
- No need to move levels for calibration.
- Overfill Capable probes allow for “true level” measurement all the way up to the process seal, without the need for special algorithms.
- 4-button keypad and graphic LCD display allow for convenient viewing of configuration parameters and echo curve.
- Proactive diagnostics advise not only what is wrong, but also offer troubleshooting tips.
- Nine common tank shapes for volumetric output.
- 30-point custom strapping table for uncommonlyshaped tanks.
- Two standard flumes and four standard weirs of various sizes for flow measurement.
- Generic flow equation for non-standard channels.
- 360° rotatable housing can be separated from probe without depressurizing the vessel.
- Probe designs up to +850 °F/6250 psi (+450 °C/431 bar).
- Saturated steam applications up to 3000 psi (207 bar),+800 °F (+425 °C) when installed in side-mounted chamber.
- Cryogenic applications down to -320 °F (-196 °C).
- Transmitter can be remote-mounted up to 12 feet (3.6 m) away from the probe.
- SIL certification allows use in SIL 2/3 Loops
- No moving parts.
- FOUNDATION fieldbus™, PROFIBUS PA and Modbus digital outputs.
- Lloyd’s Register steam drum approval
Applications of Eclipse Model 706 Wave Radar Level Transmitter
MEDIA: Liquids, solids, or slurries; hydrocarbons to waterbased media (Dielectric Constant εr = 1.2–100)
VESSELS : Most process or storage vessels up to rated probe temperature and pressure.
CONDITIONS : All level measurement and control applications including process conditions exhibiting visible vapors, foam, surface agitation, bubbling or boiling, high fill/empty rates, low level and varying dielectric media or specific gravity
https://www.gmsthailand.com/product/eclipse-model-706-transmitter/ (https://www.gmsthailand.com/product/eclipse-model-706-transmitter/)
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Eclipse Model 705 for industrial applications
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The Enhanced Eclipse Model 705 Transmitter is a looppowered, 24 VDC liquid-level transmitter based on the revolutionary of technology on Guided Wave Radar (GWR).
Encompassing a number of significant engineering accomplishments, Eclipse Model 705 is designed to provide measurement performance well beyond that of many traditional technologies, as well as “through-air” radar.
About Eclipse Model 705, the innovative enclosure is a first in the industry, orienting dual compartments (wiring and electronics) in the same plane, and angled to maximize ease of wiring, configuration, and data display. One universal transmitter can be used with all probe types and offers enhanced reliability for use in SIL 2/SIL 3 hardware systems. ECLIPSE supports the FDT/DTM standard and, with the PACTware™ Frame Program, allows for additional configuration and trending flexibility
Technology of Eclipse Model 705 for industrial applications
OVERALL LEVEL
The Eclipse Model 705 Guided Wave Radar is based upon the technology of TDR (Time Domain Reflectometry). TDR utilizes pulses of electromagnetic energy transmitted down a wave guide (probe). When a pulse reaches a liquid surface that has a higher dielectric constant than the air (εr of 1) in which it is traveling,the pulse is reflected. The transit time of the pulse is then measured via ultra speed timing circuitry that provides an accurate measure of the liquid level.
(https://www.gmsthailand.com/wp-content/uploads/2021/10/Eclipse-Model-705-for-industrial-1.jpg)
INTERFACE LEVEL
The Eclipse Model 705 is capable of measuring both an upper liquid level and an interface liquid level. Even after the pulse is reflected from the upper surface, some of the energy continues down the GWR probe through the upper liquid. The pulse is again reflected when it reaches the higher dielectric lower liquid. It is required that the upper liquid has a dielectric constant between 1.4 and 5,and the lower liquid has a dielectric constant greater than 15. A typical application would be oil over water, with the upper layer of oil being non-conductive (εr ≈ 2.0),and the lower layer of water being very conductive (εr ≈ 80). The thickness of the upper layer must be > 2″(50 mm). The maximum upper layer is limited to the length of the GWR probe, which is available in lengths up to 40 feet (12 meters).
(https://www.gmsthailand.com/wp-content/uploads/2021/10/Eclipse-Model-705-for-industrial-2.jpg)
EMULSION LAYERS
As emulsion (rag) layers can decrease the strength of the reflected signal, the ECLIPSE Model 705 is recommended for applications that have clean, distinct layers. The ECLIPSE Model 705 will tend to detect the top of the emulsion layer. Contact the factory for application assistance regarding emulsion layers.
Features of Eclipse Model 705 for industrial applications
- “TRUE LEVEL” measurement—not affected by media characteristics (e.g., dielectrics, pressure, density, pH, viscosity, etc.)
- Two-wire, 24 VDC loop-powered transmitter for level, interface, or volume.
- 20-point custom strapping table for volumetric output.
- 360° rotatable housing can be dismantled without depressurizing the vessel.
- Two-line, 8-character LCD and 3-button keypad.
- Probe designs: up to +800 °F / 6250 psi (+430 °C / 430 bar).
- Saturated steam applications up to 2250 psi @+650 °F (155 bar @ +345 °C).
- Cryogenic applications down to -320 °F (-196 °C).
- Integral or remote electronics (up to 12 feet (3.6 m)).
- Certified for use in SIL 2/SIL 3 Loops (full FMEDA report available).
Applications of Eclipse Model 705 for industrial applications
MEDIA : Liquids or slurries; hydrocarbons to water-based media (dielectric 1.4 – 100).
VESSELS : Most process or storage vessels up to rated probe temperature and pressure.
CONDITIONS : All level measurement and control applications including process conditions exhibiting visible vapors, foam, surface agitation, bubbling or boiling, high fill/empty rates, low level and varying dielectric media or specific gravity.
https://www.gmsthailand.com/product/eclipse-model-705-industrial/ (https://www.gmsthailand.com/product/eclipse-model-705-industrial/)
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Eclipse Model 700 Guided Wave Radar Level Transmitter
(https://www.gmsthailand.com/wp-content/uploads/2021/10/Eclipse-Model-700.jpg)
The Eclipse Model 700 Transmitter is a loop-powered, 24 VDC level transmitter that is based upon the proven and accepted technology of Guided Wave Radar (GWR).Encompassing a number of significant engineering accomplishments, this leading edge level transmitter is designed to provide measurement performance well beyond that of many of the more traditional technologies.
This single transmitter can be used in a wide variety of applications ranging from very light hydrocarbons to water-based media. One universal Model 700 transmitter can be used and interchanged with several different probe types and offers enhanced reliability as it is certified for use in critical SIL 2/3 hardware safety loops.The ECLIPSE Model 700 supports both the FDT/DTM and Enhanced DD (EDDL) standards, which allow viewing of valuable configuration and diagnostic information such as the echo curve in tools such as PACTware ™, AMS Device Manager, and various HART® Field Communicators.
Technology of Eclipse Model 700 Guided Wave Radar Level Transmitter
PRINCIPLE OF OPERATION
ECLIPSE Guided Wave Radar is based upon the technology of TDR (Time Domain Reflectometry). TDR utilizes pulses of electromagnetic energy transmitted down a wave guide(probe). When a pulse reaches a surface that has a higher dielectric constant than the air (εr = 1) in which it is traveling, a portion of the pulse is reflected. The transit time of the pulse is then measured via high speed timing circuitry that provides an accurate measure of the liquid (or solids) level. The amplitude of the reflection depends on the dielectric constant of the product. The higher thedielectric constant, the larger is the reflection.
(https://www.gmsthailand.com/wp-content/uploads/2021/10/Eclipse-Model-700-overall.jpg)
INTERFACE MEASUREMENT
The ECLIPSE Model 700 is capable of measuring both an upper liquid level and an interface liquid level. As only a portion of the pulse is reflected from a low dielectric upper surface, some of the transmitted energy continues down the GWR probe through the upper liquid. The remaining initial pulse is again reflected when it reaches the higher dielectric lower liquid. It is required that the upper liquid has a dielectric constant less than 10, and the lower liquid has a dielectric constant greater than 15. A typical interface application would be oil over water, with the upper layer of oil being non-conductive (εr ≈ 2.0), and the lower layer of water being very conductive (εr ≈ 80). The thickness of the upper layer could be as small as 2″ (50 mm) while the maximum upper layer is limited to the length of the GWR probe.
(https://www.gmsthailand.com/wp-content/uploads/2021/10/Eclipse-Model-700-Interface-level.jpg)
Features of Eclipse Model 700 Guided Wave Radar Level Transmitter
- Multivariable, two-wire, 24 VDC loop-powered transmitter for level, interface, volume, or flow.
- Level measurement not affected by changing media characteristics.
- No need to move levels for calibration.
- Overfill Capable probes allow for “true level” measurement all the way up to the process seal, without the need for special algorithms.
- 4-button keypad and graphic LCD display allow for convenient viewing of configuration parameters and echo curve.
- Proactive diagnostics advise not only what is wrong, but also offer troubleshooting tips
- Nine common tank shapes for volumetric output.
- 30-point custom strapping table for uncommonlyshaped tanks.
- Two standard flumes and four standard weirs of various sizes for flow measurement.
- Generic flow equation for non-standard channels.
- Probe designs up to +400 °F/6250 psi (+200 °C/431 bar).
- Cryogenic applications down to -320 °F (-196 °C).
- SIL certification allows use in SIL 2/3 Loops
- No moving parts.
Application of Eclipse Model 700 Guided Wave Radar Level Transmitter
MEDIA : Liquids, solids, or slurries; hydrocarbons to waterbased media (Dielectric Constant εr = 1.2–100)
VESSELS : Most process or storage vessels up to rated probe temperature and pressure.
CONDITIONS : All level measurement and control applications including process conditions exhibiting visible vapors, foam, surface agitation, bubbling or boiling, high fill/empty rates, low level and varying dielectric media or specific gravity.
https://www.gmsthailand.com/product/eclipse-model-700-guided-wave-radar-level-transmitter/ (https://www.gmsthailand.com/product/eclipse-model-700-guided-wave-radar-level-transmitter/)
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Digital E3 Modulevel Liquid Level Displacer Transmitter
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Digital E3 Modulevel Liquid Level Displacer Transmitter is an advanced, intrinsically safe two-wire instrument utilizing simple buoyancy principle to detect and convert liquid level changes into a stable output signal. The linkage between the level sensing element and output electronics provides a simple mechanical design and construction. The vertical in-line design of the transmitter results in low instrument weight and simplified installation. The instrument comes in avariety of configurations and pressure ratings for varied applications.The Digital E3 Modulevel has microprocessor-based electronics with 4–20 mA/HART® or FOUNDATION fieldbus™ output. E3 supports the FDT/DTM standard and a PACTware™ PC software package allows for additional configuration and trending capabilities.
Technology of Digital E3 Modulevel Liquid Level Displacer Transmitter
Changing buoyancy forces caused by liquid level change act upon the spring supported displacer causing vertical motion of the core within a linear variable differential transformer.As the core position changes with liquid level, voltages are induced across the secondary windings of the Digital E3 Modulevel Liquid Level Displacer Transmitter.These signals are processed in the electronic circuitry and converted to a useable output signal. The enclosing tube acts as a static isolation barrier between the Digital E3 Modulevel Liquid Level Displacer Transmitter and the process media.
Features of Digital E3 Modulevel Liquid Level Displacer Transmitter
- Two-wire, loop-powered, transmitter for level, interface or density measurement
- No level change needed for configuration; no field calibration necessary.
- Safety Integrity Level (SIL) Certified, SFF value of 90.6%
- 4 –20 mA output signal
- Two-line, 8-character LCD and 3-button keypad
- Continuous self-test with 22 mA, 3.6 mA or Hold fault indication fully compliant with NAMUR NE 43
- Comprehensive diagnostics with faults, warnings & status history
- HART or FOUNDATION fieldbus digital communications
- PACTware PC program using HART communication for advanced configuration and troubleshooting (see bulletin 59-101)
- IS, XP and Non-incendive approvals by FM, CSA, ATEX, IEC
- Standard output range from 3.8 to 20.5 mA
- 11 VDC turn on voltage
- Maximum loop resistance of 620 ohms at 24 VDC
- Process temperatures to +835 °F (+445 °C) for non-steam applications
- Level ranges from 14 to 120+ inches (356 to 3048+ mm)
- Specific gravity as low as 0.23
- Cast aluminum or stainless steel, TYPE 4X, Cl I Div 1 Groups B, C, D housing
- Field wiring in isolated junction box
- Head rotatable through 360°
- Accepted proven LVDT/range spring technology
- Range spring suppresses effects of turbulence to produce stable output signal.
- Flanged top mounting or external cage with side/side or side/bottom connections
- Special options, materials of construction and custom engineered features available (consult factory).
- Spring protector standard
- Signal sampling 15 times per second
- Non-interacting zero and span
- Emission and immunity compliance to EN 61326
- Specific gravity adjustment without stopping process
- Signal damping adjustment
- 64-unit multi-drop capability
- Consult factory for ASME B31.1, ASME B31.3 or NACE construction.
Application of Digital E3 Modulevel Liquid Level Displacer Transmitter
MEDIA: Liquids or slurries, clean or dirty, light hydrocarbons to heavy acids (SG=0.23 to 2.20)
VESSELS: Process & storage, bridles, bypass chambers, interface, sumps & pits up to unit pressure & temperature ratings.
CONDITIONS: Most liquid level measurement and control applications including those with varying dielectric, vapors, turbulence, foam, buildup, bubbling or boiling and high fill/empty rates. Also, liquid/liquid interface level measurement or density control.
https://www.gmsthailand.com/product/digital-e3-modulevel-liquid-level-displacer-transmitter/ (https://www.gmsthailand.com/product/digital-e3-modulevel-liquid-level-displacer-transmitter/)
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Advanced Apura Gas Separation Membrane
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To meet pipelines tranmission specifications, gas processing operations treat or condition produced gas that contains acid gases. Theses acid gases need to be removed because they lower the heating vale of natural gas and accelerate the corrosion of pipelines and transmission control equipment. Apura Gas Separation Membrane from Fujifilm demontrated excellent CO2 and H2S seperation capabilities and proved to recover more hydrocarbons compared with traditional spiral-wound membranes
Overview – Apura Gas Separation Membrane
No chemical usage and >30% more recovery of saleable hydrocarbons
The Apura gas separation membrane is a durable, spiral-wound, multilayer composite membrane. It is ideally suited to seamlessly replace traditional cellulose acetate (CA) spiral-wound elements for acid gas removal to meet pipeline transmission specifications.
Apura membranes are designed for use in high-pressure, medium- to low-CO2 applications for bulk and fine removal of contaminants such as water, CO2, and H2S. The smaller ecological footprint—reduced power consumption and zero chemical requirements—provides substantial savings on total cost of ownership and releases fewer emissions compared with amine systems.
Advantages
- Increases recovery of saleable hydrocarbons by 30% or more compared with traditional CA spiral-wound membranes
- Extends membrane life up to 40% in water-rich conditions
- Enables simple plug-and-play replacement of CA spiral-wound membranes
- Releases fewer emissions than amine systems
- Eliminates chemical requirements
- Reduces power requirements
Application of Apura Gas Separation Membrane
Feed gas enters from the side of the spiral-wound Apura membrane, enabling smaller molecules, such as CO2 and H2S, to pass through the multiple layers in a crossflow manner. They then enter the central perforated tube at lower pressure. The high-pressure nonpermeate gasstream, rich in hydrocarbons and depleted of CO2, flows to the next section of membrane modules to repeat this process until the necessary product gas specifications are met. The low-pressure CO2-rich permeate stream is collected in the central perforated tube and routed to the desired location as a wastestream. Apura membranes are available in 8-in and 8.25-in diameters.
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(https://www.gmsthailand.com/wp-content/uploads/2021/09/Apura-Gas-Separation-Membrane-3.jpg)
https://www.gmsthailand.com/product/apura-gas-seperation-membrane/ (https://www.gmsthailand.com/product/apura-gas-seperation-membrane/)
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Amine gas treating system with field-proven
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Hydrogen sulfide, Carbon dioxide,and other contaminations are often found in natural gas streams. Amine gas treating systems remove these contaminations so that the gas is suitable for transportation and use.
Overview – Amine gas treating systems
Prepare natural gas for commercialization
Custom and standard Amine gas treating systems remove CO2 and H2S, resulting in gas with <2-mol% CO2 and <4-ppm H2S. Efficiently removing CO2, H2S, and mercaptans makes the gas suitable for transportation and use.
The amine plant can be installed as a stand-alone component or as a part of an integrated processing system. We can custom engineer solutions for amine recirculation rates above 700 galUS/min [2.64 m3/min], and we offer five standardized designs for rates below 700 galUS/min. Years of gas sweetening expertise is built into the design and engineering of our standardized gas plants. So you can expect to achieve performance comparable to a custom-designed sweetening plant.
Amine treating advantages
- Various heat sources (direct-fired, waste heat, hot oil, and steam systems) can be used for the still reboiler.
- Customized plants can be designed to customer specification while maintaining fast delivery.
- Our amine systems can meet required CO2 and H2S levels operating with multiple solvent types and recirculation rates.
- Standard system designs reduce manufacturing and commissioning times.
- Amine systems are easily combined with other technologies into hybrid systems for many sizes of gas sweetening projects.
Application of Amine gas treating systems
Amine sweetening process as following:
1. Sour gas enters the contactor tower and rises through the descending amine solution.
2. Purified gas flows from the top of the tower.
3. The amine solution, carrying absorbed acid gases, leaves the tower for the heat exchanger or optional flash tank.
4. Rich amine is heated by hot regenerated lean amine in the heat exchanger.
5 Rich amine is further heated in the regeneration still column, by heat supplied from the reboiler.
6. Steam and acid gases separated from the rich amine are condensed and cooled, respectively, in the reflux condenser.
7. Condensed steam is separated in the reflux accumulator and returned to the still. Acid gases may be vented, incinerated, or directed to a sulfur recovery system.
8. Hot regenerated lean amine is cooled in a solvent aerial cooler and circulated to the contactor tower, completing the cycle.
9. A variety of heat sources can be used for the still reboiler—direct fired, waste heat, hot oil, and steam systems.
(https://www.gmsthailand.com/wp-content/uploads/2021/09/Amine-Process.png)
https://www.gmsthailand.com/product/amine-gas-treating-system-with-field-proven/ (https://www.gmsthailand.com/product/amine-gas-treating-system-with-field-proven/)
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Cyclotech B Series deoiling hydrocyclone
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CYCLOTECH B Series deoiling hydrocyclone technologies represent the state of art in produced water treatment technology, a third-generation geometry optimizing the critical balance between oil-removal efficiency and capacity. Leveraging a globally installed based on both onshore and offshore facilities, the technologies ensure that peak separation is achieved in the most cost-effective and space efficient manner.
Overview – Cyclotech B Series Deoiling hydrocyclone
Balancing efficiency and throughput capacity in a reliable, wear-resistant separation solution
Deoiling hydrocyclone technologies represent the state of the art in produced water treatment, optimizing the critical balance between oil-removal efficiency and throughput capacity. Achieving this balance yields peak separation in the most cost-effective and space-efficient manner. These technologies have a global track record in onshore and offshore facilities.
(https://www.gmsthailand.com/wp-content/uploads/2021/09/CYCLOTECH-Cyclonic-Separation-Technologies-1.jpg)
CYCLOTECH Cyclonic Separation Technologies
Having no moving parts, CYCLOTECH B Series hydrocyclone technologies achieve liquid-liquid separation using a pressure drop across the unit. Their liners are manufactured from a range of wear-resistant materials, including tungsten carbide or reaction-bonded silicon carbide. An advanced ceramic that extends wear life up to 10 times beyond a standard duplex stainless steel liner is also available.
B Series technologies treat waterstreams containing up to 2,000 mg/L of oil to meet a discharge-water oil content of 30 mg/L—or more commonly, stretch targets as low as 15 mg/L.
With special features
- Improved reliability – Use of no moving parts and wear-resistant materials
- Smaller footprint – Compact design uses less space
- More efficiency – Retrofit capability increases capacity and separation performance
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CYCLOTECH Cyclonic Separation Technologies
Application of Cyclotech B Series Deoiling hydrocyclone
Operating with no moving parts, B Series technologies achieve liquid-liquid separation using a pressure drop across the unit. Oily water is forced under pressure into the inlet section of the liner via a tangential inlet port. This pressure, together with narrow cyclone diameter, causes the fluid to spin at high velocity, creating a high gradial acceleration field. Oil, the less-dense liquid, is forced to the axial center of the hydrocyclone to form a thin oil core. Through internal hydrodynamic forces and external differential pressure control, this oil core is removed via the reject ports of the hydrocyclone liners; the clean water flow is discharged from the cyclone underflow.
https://www.gmsthailand.com/product/cyclotech-b-series/ (https://www.gmsthailand.com/product/cyclotech-b-series/)
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Glycol Dehydration Systems for water removal
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Schlumberger Glycol dehydration systems remove water vapor from natural gas, which helps prevent hydrate formation and corrosion and maximixes piplines efficiency.
Overview – Glycol dehydration systems
Efficient removal of water and impurities from natural gas streams
Our triethylene glycol dehydration system is among the most widely used in the oil and gas industry because of low operating costs and relatively low capex. Glycol dehydration systems are not only efficient at removing water from a natural gas stream, they also remove benzene, toluene, ethylbenzene, and xylene (BTEX) as well as other volatile organic compounds (VOCs).
In natural gas systems, removing water vapor reduces pipeline corrosion and eliminates line blockage caused by hydrate formation. The water dewpoint needs to be below the lowest pipeline temperature to prevent free-water formation.
Using amine treatment to remove acid gases results in water-saturated gas that must be dehydrated before entering the pipeline. Most product specifications require the maximum quantity of water in the gas to be 4 to 7 lbm/MMcf.
Advantages
- Suitable for a wide range of flow, pressure, and temperature conditions
- Lower operating costs than conventional desiccants
- Lower capex than solid bed systems
- Custom and standard units, which can employ either bubble cap or structured packing
- Reduced manufacturing and commissioning times for standard system designs
- Easily packaged hybrid systems (amine packaged with glycol dehydration systems) for small to large gas sweetening requirements
Application of Glycol dehydration systems
In our glycol dehydration system, wet gas enters a tower at the bottom and flows upward. Dry glycol flows down the tower from the top, from tray to tray or through packing material.
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Our special bubble cap configuration maximizes gas-glycol contact, removing water to levels below 5 lbm/MMcf. Advanced systems can be designed to achieve levels less than 1 lbm/MMcf.
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The dehydrated gas leaves the tower at the top and returns to the pipeline or goes to other processing units. The water-rich glycol leaves the tower at the bottom and goes to the reconcentration system, where it is filtered to remove impurities and heated to 400 degF [204 degC]. Water escapes as steam, and the purified glycol returns to the tower where it again contacts wet gas.
The entire system operates unattended. Controllers monitor pressures, temperatures, and other aspects of the system to maximize safety and efficiency.
https://www.gmsthailand.com/product/glycol-dehydration-systems-3/ (https://www.gmsthailand.com/product/glycol-dehydration-systems-3/)
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PUREMEG Monoethylene glycol (MEG) reclamation and regeneration system
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Monoethylene glycol (MEG) reclamation is widely used by the oil and gas markets in wellheads and pipelines to prevent hydrate formation at pipeline conditions. In offshore deepwater gas production facilities, where the exposure to lower temperatures in subsea pipelines is common , MEG is used for hydrate inhibition.
Overview – PUREMEG Monoethylene glycol (MEG) reclamation and regeneration system
Minimize MEG deterioration and losses and reduce operating and environmental costs
Monoethylene glycol (MEG) reclamation is one of the most commonly used reagents for hydrate inhibition in production pipelines. It is recovered and reinjected to minimize the operating and environmental costs associated with MEG replacement and disposal.
PUREMEG MEG reclamation and regeneration systems not only regenerate the MEG by boiling off the pipeline water, they also remove salts and other solids to achieve the required outlet glycol purity. Dissolved salts in formation water, pipeline production chemicals, and pipe scale all have the potential to scale or foul both subsea and topside processing equipment. This MEG recovery system is an essential component of pipeline flow assurance.
Improve operational efficiency, increase plant availability, and maintain asset integrity
In addition to our reclamation technology, we provide everything from customized site support contracts covering training, installation, commissioning, and startup to long-term operational assistance, data acquisition, conditional monitoring, and predictive maintenance services.
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PUREMEG Monoethylene glycol (MEG) reclamation and regeneration system
Advantages
- The system provides effective and proven salt removal.
- Low solids levels in the recycle loop protect the most expensive and vulnerable parts of the system from abrasion, erosion, and fouling, which reduces maintenance and increases plant availability.
- Low solids levels in the recycle loop protect the most expensive and vulnerable parts of the system from abrasion, erosion, and fouling, which reduces maintenance and increases plant availability.
- The technology significantly reduces Monoethylene glycol (MEG) reclamation losses and produces a wastestream suitable for marine disposal by separating salt from brine.
- Solids removal is achieved without the use of centrifuges, unlike other systems on the market. This avoids use of expensive, high-maintenance equipment and prevents oxygen contamination of the Monoethylene glycol (MEG) reclamation. Oxygen is a main contributor to MEG degradation and material corrosion within reclamation systems, affecting both opex and the life of the plant.
- The MEG reboiler is designed to avoid hydrocarbon foaming and the fouling of packing associated with conventional systems.
- The proprietary divalent salt removal system is capable of handling a diverse range of water chemistries, solids loadings, and particle-size distributions.
- The dedicated reaction vessel optimizes crystal growth in the precipitation of divalent salts. Crystal size and shape directly influence the performance of downstream separation and drying processes.
- A wash step is included as part of the divalent salt removal system, enabling MEG recovery and reducing opex; the salt discharge can be dried for easier handling and disposal
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Monoethylene Glycol (MEG) Reclamation & Regeneration
Five-step process to regenerate MEG and remove salts
The PUREMEG system is configured with either a full-stream or slipstream process. Full stream both regenerates and removes salts from the rich MEG feed. Slipstream has full-feed MEG regeneration, with a portion of the lean of Monoethylene glycol (MEG) reclamation. Our experts can advise you which option best suits your process requirements. In either case, the process comprises five steps: pretreatment, MEG regeneration, flash separation, salt management, and divalent salt removal.
1) Pretreatment
In the pretreatment stage, the rich MEG—containing some dissolved gas and hydrocarbon liquids—is heated and passed through a three-phase separator vessel. The gas is flashed to flare and liquid hydrocarbons are sent to the condensate recovery system. The treated MEG is sent either to storage or the downstream process.
2) MEG regeneration
MEG regeneration is conducted in a reflux distillation column. For a slipstream process, the column operates off the low-pressure flare backpressure and is provided with a pump-around heating loop. For a full-stream system, the distillation column operates under vacuum conditions.
The lean MEG produced at the bottom of the column is pumped to storage for reuse. For the slipstream service, a portion of the lean MEG is sent for reclamation. The vaporized water passes overhead where it is condensed and collected in the reflux drum. A portion of the water is returned to the distillation column to provide reflux while the remainder is routed to water treatment. Residual hydrocarbons in the system are generally associated with this produced water stream, and we provide a wide range of water treatment systems capable of meeting local environmental legislation for discharge.
3) Flash separation (reclaimer)
In the flash separator, the rich MEG stream (full-stream reclamation) or lean MEG stream (slipstream reclamation), consisting of water and MEG with dissolved salts, is brought into contact with a hot recycled stream of concentrated MEG. The flash separator operates under vacuum conditions to maintain process temperatures below the degradation temperature of MEG. The feed MEG and water are vaporized and exit through the top of the flash separator. These vapors either pass to the MEG distillation column for regeneration (full-stream service) or are condensed and sent to lean MEG storage (slipstream service). The monovalent salt components, primarily sodium chloride, precipitate in the flash separator. They fall via gravity through a column of brine and are collected in the brine-filled salt tank.
4) Salt management
The salt tank serves two primary functions. The first is to condition the salt levels for optimal performance of the salt separation process. The second is to provide a surplus of salt for converting freshwater makeup to saturated brine. Salt is removed from the brine by a hydrocyclone to produce a slurry suitable for a landfill or for redissolving for marine disposal.
5) Divalent salt removal
Divalent salts (typically calcium, magnesium, and iron but also barium and strontium) cannot be precipitated out in the flash separator. Instead they accumulate in the process, which has an impact on system operability. For a slipstream process, the salts are often a cause of scaling within the reboiler. Removing the salts by MEG blowdown can be cost-prohibitive once disposal and replenishment costs are considered.
The divalent salt removal system precipitates out the salts by chemical reaction to form insoluble salts. Crystal size and shape directly influence the performance of the downstream filter. A dedicated reactor vessel is provided to control the temperature, time, and concentration for optimal crystal growth and morphology. Both sodium carbonate and sodium hydroxide are used for the chemical reaction to account for variations in feed conditions. The crystals, together with any other solids such as pipe scale and sand, are removed by filtration. Typically a dynamic crossflow filter is used for this service because of its tolerance for a wide range of particle sizes and distribution. The filter produces a clean MEG stream, which is returned to the process, and a concentrated slurry or cake, which is washed to recover any residual MEG. The produced slurry or cake can be further dried to provide a waste product that is easy to store and handle.
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Typical PUREMAG system with full-stream reclamation
https://www.gmsthailand.com/product/puremeg-monoethylene-glycol-meg-reclamation-and-regeneration-system/ (https://www.gmsthailand.com/product/puremeg-monoethylene-glycol-meg-reclamation-and-regeneration-system/)
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What is LNG Storage Tank? and what it’s used for?
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In the shipping sector, liquefied natural gas (LNG) has firmly established itself as the fuel of choice for the future, according to a wide range of participants. Despite this upbeat outlook, one of the most significant barriers to switching to natural gas is the expensive initial investment required for LNG storage facilities. Supplier is continuing to investigate innovative ways of integrating technology in order to provide cost-effective storage solutions for gas-fueled boats of any size and LNG installed volume, regardless of their fuel source.
Shipping is a truly global business with fierce competition on an ongoing basis. Increased public pressure to reduce the sector’s environmental effect only serves to increase customers’ desire to lower their expenses. In order to save money and stay one step ahead of the competition, it may be necessary to implement innovative new solutions or repurpose existing technology from other industries. The latter method is often less complicated, involves less risks, and results in a shorter time to market. The evaluation of current technologies and their cost drivers, as a consequence, may aid in the creation of strategies for overcoming implementation roadblocks. Of course, each Supplier solution takes into account the unique needs of each customer, but this research outlines a few of the ways in which Supplier may help more customers in realizing the environmental and economic benefits of LNG.
Installations and equipment for liquefied natural gas – EN 1473
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Cryogenic Liquid Vacuum Storage Tank
Euronorm It is the European standard EN 1473 Installation and equipment for liquefied natural gas, which serves as the overarching document for the design, building, and operation of all onshore LNG facilities. It includes installations for liquefaction and regasification, as well as storage facilities, which are often referred to as tanks in the industry. Environment compatibility, safety needs, risk assessments, and safety engineering are all addressed in detail in EN 1473, which specifies terminology and imposes standards to be taken into consideration throughout the design process. These LNG facilities are specified in detail in the standard and in Annex G: – LNG export terminal; – LNG receiving terminal; – LNG peak-shaving plants; and – LNG satellite plants.
Some parts of this standard have a direct impact on the design and construction of concrete tanks, while others have a less direct impact. This includes suggestions on how to evaluate safety and environmental compatibility, which are included in Chapter 4, for example. A thorough environmental impact assessment (EIA) must be carried out after the site has been determined. It is necessary to do this evaluation in order to determine the total amount of solids, liquids, and gases released by the facility during both regular operation and accidents. It is essential that plants be built in such a manner that gas is not constantly flared or vented, but is instead recovered to the greatest extent feasible, and that hazards to persons and property both within and outside the facility are minimized to a level that is widely considered acceptable. The study of the site may provide load scenarios that are important for the design, such as tsunamis or blast pressure waves,amongst other possibilities. It is necessary to include information on the existence of karst, gypsum and swelling clays in geological and tectonic soil surveys, as well as the susceptibility of the soil to liquefaction, the physical formation process, and the possibility for seismic activity in the future.
When constructing an LNG plant, it is necessary to do a risk assessment. The guidance in Annexes I, J, and K (which are given only for informational reasons) pertains to establishing frequency ranges, classes of consequence, degrees of risk, and acceptance criteria, among other things. A risk category is given to the plant based on a study of frequency ranges and consequence classes, and the plant is assigned to one of three risk categories. If the risk is acceptable, it must be lowered to a level that is as low as reasonably practicable (ALARP), if it is unacceptable, it falls into one of the categories listed above. In the annexes, the values specified are minimum requirements that may be increased by national laws or project specifications.
When doing a hazard and operation study (HAZOP), risk assessment is often included, but other methods are also allowed, such as failure mode and effect analysis (FMEA), event tree method (ETM), and fault tree method (FTM). It is necessary to categorize plant systems and components based on their relevance to safety within the scope of the risk assessment. Here, there is a division into two categories: class A, which includes systems that are critical to plant safety or protection systems that must be kept operational to ensure a minimum level of safety; and class B, which includes systems that perform functions that are critical to plant operation or systems whose failure could result in a major impact on the environment or create an additional hazard.
Sections 6.3 and 6.4 are particularly important for the design of concrete storage tanks, respectively. Section 6.3 and Annex H include specifics and illustrations of the different tank types, information that is complemented by the more comprehensive requirements of EN 14620 Part 1 (European Standard for Pressure Vessels). Because it covers spherical tanks as well as concrete tanks with both the main and secondary containers constructed of prestressed concrete, EN 1473 goes farther than EN 14620 in terms of the information that it provides. 6.4 defines design principles, which include criteria for fluid-tightness, maximum and minimum pressures, tank connections, thermal insulation, instrumentation, heating, and liquid level restrictions, among other things. These principles allow for the development of design criteria for the architecture of the facility, the minimum distance between tanks, and the consideration of potential sources of danger such as fire or blast pressure wave, among other things.
Construction of LNG Tanks – EN 14620 The European Standard EN 14620, which specifies the design and manufacture of site-built vertical, cylindrical, flat-bottomed steel tanks for the storage of refrigerated, liquefied gases with operating temperatures ranging from zero degrees Celsius to one hundred and sixty degrees Celsius, is divided into five parts:
Part 1: Overarching Concepts
Part 2: Components made of metal
Part 3: Components made of concrete
Part 4: Components of the insulation
Part 5: Testing, drying, purging, and cooling-down procedures.
Types of LNG Storage Tanks
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Type of LNG tanks
Liquefied gas storage tanks are classified according to their kind and size according to a variety of standards and rules that vary in terms of when they were issued as well as the amount of information they provide. The two German standards, DIN EN 1473 and DIN EN 14620, are even diametrically opposed in terms of the language they use. This section will make use of either the terminology found in the British counterpart, BS EN 1473, or the terms found in API 625. BS EN 1473 is the British equivalent of API 625. From a practical standpoint, the term “containment tank system,” as used in API 625, seems to be the most suitable, since the many, but coordinated, components work together to form a cohesive system as a result of their interaction. According to the standards EEMUA, BS 7777, EN 1473, EN 14620- 1, NFPA 59A, and API 625, containment tank systems may be classified as single, double, or complete containment tank systems. There is one additional tank type that is described in more depth in the European standards EN 1473 and EN 14620, and that is the membrane tank.
Until the 1970s, the only kind of tank that was constructed was the single-wall tank. It was the hazard scenarios resulting from abnormal actions such as failure of the inner tank, fire, blast pressure wave, and impact that inspired the subsequent further development of the various types of tanks or tank systems, and the associated requirements placed on the materials and construction details. Because of the dangers that a tank failure poses to the surrounding regions, it is essential to choose the appropriate kind of tank system.
It will be shown, using the failure of the inner container, the consequences of such a failure on the tank as a whole and its surroundings for three widely used tank systems. It will also be discussed how these three tank systems have evolved over time.
https://www.gmsthailand.com/blog/what-is-lng-storage-tank/ (https://www.gmsthailand.com/blog/what-is-lng-storage-tank/)
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Cameron choke valve – flow control industry standard
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Cameron’s choke valve is designed to provide precise flow control throughout their entire operating range, with a well-proven track record in the field :
Overview – Control Choke valve
Cameron’s control choke valve is designed to provide precise flow control throughout their entire operating range, with a well-proven track record in the field :
- Control choke valve is suitable for a wide variety of applications, including production, injection, artificial lift, flowback, storage, etc.
- Commonly installed on Christmas trees, manifolds, line heaters, offshore platforms, FPSOs, and other equipment, providing precise flow control under severe service conditions.
- Available with plug & cage, external-sleeve or multistage trim types.
- Multiple flow characteristics, including ‘linear’ or ‘equal percentage’, with special trim solutions available in response to specific challenges.
- Special trim solutions include ultra-low Cv, low noise, and well cleanup types.
- Control chokes offer a complete solution from startup to late life conditions, with the flexibility to easily retrofit various trim types as conditions evolve.
- Available in manual and actuated configurations, including multiple actuator types.
Application of Cameron’s Control Choke Valve
- Selection of the correct trim size and type is vital to the successful and reliable operation of a choke. Cameron offers a computer-based choke sizing program to optimize choke sizing and selection for you.
- Based on flow and pressure requirements of the application, the program analyzes and specifies the optimal choke size and trim configuration.
- Features of the program include
- capability to size a large number of chokes and flow conditions
- modular sizing program structure that enables the addition of new choke and choke trim data updates as needed
- graphics capabilities
- project worksheet and Cv curve printouts
- choke sizing per ANSI/ISA S75.01 specifications
- flow testing per ANSI/ISA S75.02 specifications
- noise prediction and testing per ANSI/ISA S75.07 specifications.
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External Sleeve Control Choke for low-capacity, high-pressure-drop applications
- The external sleeve control choke has a sleeve that throttles the flow on the external diameter of the ported cage. The external sleeve trim is particularly suited for low-capacity/high pressure-drop applications. The external sleeve is designed specifically for severely erosive service where the combination of high pressure drops and high sand concentrations can reduce the life of a choke.
- Available in various sizes ranging from CC15 to CC80 choke models.
- Tungsten carbide-lined external sleeve and solid tungsten carbide cage/seat provide optimum wear resistance in erosive conditions.
- Metal body-to-bonnet gasket for absolute pressure containment.
- Reverse angle external sleeve improves flow dynamics within the trim.
- Self-flushing, pressure-balanced ports reduced stem loads and actuator output requirements.
- Heavy-duty thrust bearings reduce operating torque.
- Pressure-balance seals are a key feature of the pressurbalanced trim arrangement, reducing operating forces and enabling greater ease of adjustment.
Features
- Large visual indicator provides position in 1/64 in (bean) as standard.
- External grease port lubricates threads and bearings.
- Stem lock maintains set position.
- Bleed plug assembly vents pressure before disassembly.
- Antirotation key translates rotation from the drive bushing into linear movement of the lower stem/flow plug assembly.
- Two-piece stem is threaded and locked, and is removed from wellbore fluids.
- Large annulus area reduces the risk of body and trim erosion caused by high velocities.
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All control chokes are available in manually operated or actuated models. Custom-designed trim components to suit a wide variety of Cv capacities and flow characteristics also are available
Plug & Cage Control choke
- The plug and cage control choke uses the plug as the controlling element and throttles the flow on the internal diameter of the ported cage. The ports in the cage are sized and arranged to give the most appropriate combination of control and flow capacity for each application.
- A major consideration when sizing the choke is the ability to closely manage well startup while optimizing capacity toward the end of well life to maximize production.
- The plug and cage design is highly optimized and incorporates the largest-possible flow area, making it ideal for high-capacity applications. Plug and cage chokes also are constructed with a solid tungsten carbide plug tip and inner cage for extended resistance to erosion. These valves may further be configured with a solid tungsten carbide wear sleeve in the outlet of the body to provide enhanced protection in sandy service.
This trim also includes a thick metal outer cage to ensure maximum protection against solid impacts from debris in the flow. The combined result is a versatile, robust, erosion-resistant trim with suitability for a broad range of challenging applications.
- Available in various sizes ranging from CC15 to CC80 choke models.
- Tungsten carbide plug tip in conjunction with solid tungsten carbide cage optimizes wear resistance in erosive conditions.
- Metal body-to-bonnet gasket for absolute pressure containment.
- Fully guided plug reduces side loading and vibration.
- Self-flushing, pressure-balanced ports reduce stem loads and actuator output requirements.
- Heavy-duty thrust bearings reduce operating torque.
- Pressure-balance seals are a key feature of the pressure-balanced trim arrangement, reducing operating forces and enabling greater ease of adjustment.
- Metal outer cage protects from impact damage.
The control choke model
CC15 Control Choke Valve
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CC20 Control Choke Valve
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CC30 Control Choke Valve
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High Temp and High Pressure Application
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https://www.gmsthailand.com/product/cameron-control-choke-valve/ (https://www.gmsthailand.com/product/cameron-control-choke-valve/)
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The Jupiter® JM4 magnetostrictive level transmitter
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The Jupiter® JM4 magnetostrictive level transmitter is a loop-powered 24 VDC liquid-level transmitter and is available as a direct insertion transmitter or as an external mounted transmitter onto a Magnetic Level Indicator. It relies on the position of a magnetic float which is designed precisely for the liquid to be measured. This high-accuracy device can be designed for liquid level and/or liquid-liquid interface measurement.
Principle
The Jupiter JM4 magnetostrictive level transmitter is a loop-powered 24 VDC liquid-level transmitter and is available as a direct insertion transmitter or as an external mounted transmitter onto a Magnetic Level Indicator. It relies on the position of a magnetic float which is designed precisely for the liquid to be measured. This high-accuracy device can be designed for liquid level and/or liquid-liquid interface measurement.
Technology of JM4 magnetostrictive level transmitter
Magnetostriction
A low-energy pulse, generated by the JUPITER electronics, travels the length of the magnetostrictive wire. A return signal is generated from the precise location where the magnetic field of a float intersects the wire. A timer precisely measures the elapsed time between the generation of the pulse and the return of the acoustic signal. Each cycle occurs ten times per second, providing real-time and highly accurate level data.
How magnetostriction works
LOW-VOLTAGE PULSE
On-board electronics send a low-voltage electrical pulse down the magnetostrictive wire at the speed of light, ten times per second.
MAGNETS
Magnets contained within the float focus their energy toward the wire at the precise location of the liquid level.
PIEZOELECTRIC CRYSTALS
The mechanical wave is converted back into electrical energy by two piezoelectric crystals. The on-board electronics interpret the time-of-flight data and indicate the position of the float magnets.
TWIST
Interaction between the magnetic field, electrical pulse, and magnetostrictive wire cause a slight mechanical disturbance in the wire that travels back up the probe at the speed of sound.
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Features of JM4 magnetostrictive level transmitter
- 4-button user interface and graphical LCD display provide enhanced depth of data, indicating on-screen waveforms and troubleshooting tips.
- 4-20 mA output
- Rotatable housing can be dismantled without depressurising the vessel via “Quick connect/disconnect” probe coupling.
- Ergonomic dual compartment enclosure
- Simple set-up and configuration
- Smart Probe Technology
- Easy attachment to an MLI
- Direct insertion for a wide variety of vessels and applications
Application of JM4 magnetostrictive level transmitter
Chemical
- Chemical injection
- Chemical injection skids
- Condenser
- Deionization tanks
- Distillation columns
- Distillation towers
- Liquid-Liquid extraction
- Neutralization
- Quench Tower/Settler
- Reboiler
- Reflux drum
- Scrubber vessels
- Steam drums for chemical industry
Natural Gas
- Chemical injection skids
- Compressor Scrubber
- Compressor Waste Liquid
- Gas Dehydration
- Natural gas separators
- NGL recovery & Storage
- Separators
- Sour gas treatment
- Sulfur Recovery
- Vapor recovery unit
Petroleum Refining
- Alkylation tanks
- Catalytic reformers
- Catalytic strippers
- Crude desalting
- Crude Dewatering
- Diesel fuel storage tanks
- Distillation columns
- Distillation towers
- Gun-barrel separators
- Horizontal separators
- Hydrocracking
- Hydrodesulfurization
- Isomerization
- Reboiler
- Separator boots
- Solvent extraction
https://www.gmsthailand.com/product/jm4-magnetostrictive-level-transmitter/ (https://www.gmsthailand.com/product/jm4-magnetostrictive-level-transmitter/)
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Magnetic level indicator Atlas™
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The AtlasTM is our standard, high performance magnetic level indicator. The ATLAS is a single-chamber design, with either 2″, 2.5″, or 3″ chamber diameter, as required by the application. There are twelve basic configuration styles, including top mount models.
ATLAS magnetic level indicators are produced in a wide range of materials of construction, including exotic alloys and plastics. We also offers one of the most complete selections of process connection types and sizes for level measurement.
The ATLAS unit may be equipped with a variety of level transmitters and switches, as well as flag and shuttle indicators with or without stainless steel scales. This enables the ATLAS magnetic level indicator to be a complete level and monitoring control.
Principle
A change of level in the process tank corresponds to a similar change within the ATLAS chamber. In response to the level movement, the ATLAS float moves accordingly, actuating the flags or shuttle for visual indication.
Technology of Magnetic level indicator Atlas™
Magnetic Level Indicators (MLI) have revolutionized the global visual indication market by offering a safer, reliable, and high-visibility alternative to common gauge glass assemblies. Utilizing a combination of proven buoyancy principles along with the benefits magnetism, MLIs can be customized to fit virtually any process connection arrangement on the vessel.
The chamber and magnetic float is available in a variety of materials and pressure ratings to accommodate the wide variety of complex process applications present in the world’s major industrial facilities.
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Features of Magnetic level indicator Atlas™
- Numerous chamber styles (or configurations) are available for each design. Consult factory for options not listed in this bulletin.
- Complete range of level switches and level transmitters
- Fabricated, non-magnetic chamber assembly produced in a wide range of metal and plastic materials
- A wide range of process connections is available
- Precision manufactured float with internal magnets and magnetic flux ring
- ASME and EN 1092-1 process connections available
- Flag or shuttle type indicator with stainless steel scale to measure height or percentage of level, volume or content
- Standard float stop springs at top and bottom of chamber
- Exceptional code qualified welding
Applications of Magnetic level indicator Atlas™
- Feedwater heaters
- Industrial boilers
- Oil/water separators
- Flash drums
- Surge tanks
- Gas chillers
- Deaerators
- Blowdown flash tanks
- Hot wells
- Vacuum tower bottoms
- Alkylation units
- Boiler drums
- Propane vessels
- Storage tanks
https://www.gmsthailand.com/product/magnetic-level-indicator-atlas/ (https://www.gmsthailand.com/product/magnetic-level-indicator-atlas/)
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LNG ISO Tank for relocatable LNG station
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Multi-layer Vacuum insulated cryogenic LNG ISO Tank is covered with double-walled shields. These are designed for efficient and cost-saving transportation.
Fixed chassis design provides excellent transportation. Even transporting in rough road, this design is strong enough to deliver in every situation.
LNG ISO container is your perfect choice for worldwide LNG transportation. The LNG ISO Tank has many customizable features. Moreover, 40-feet LNG tank is specially designed for easy transportation around the world.
LNG ISO cryogenic containers are commonly used in many countries for optimizing energy supply chains and storing liquefied natural gas in urban and rural areas. As specific customer’s requirement, customer can possibly buy or lease the containers for short or long periods. We will offer you a cost-effective solution.
Especially, LNG ISO tank and containers are designed for transportation not only on the road and rail but also in the sea and especially for international transportation.
The most outstanding function of LNG ISO Container is the ability to transport among land, railway and ocean. Gms Interneer has many partners whose enterprise passed the Ministry of Communications and national Marine Board LNG container’ test. With excellent insulation, no matter how far the transportation is, LNG ISO Container is your suitable choice in any case.
How LNG ISO Tank works ?
The main circuit of LNG ISO Tank is divided as following:
Filling
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The process starts with filling LNG into the storage tank through the E-1 and through the filling valve to the tank. Especially, the pressure must be controlled in proper level. There are two main parts:
- Bottom fill is filling LNG into the bottom of the tank containing liquid which flows directly via V-1. When LNG combines with existing LNG in the tank, it turns to faster filling. However, it will also increase the pressure of the tank.
- Top fill is filling LNG to the top of the storage tank directly via V-2. When LNG merges with gas vapor, it becomes slower filling. Moreover, it will reduce the pressure of the tank
Pressure Build-up
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To control the pressure in the storage tank, it depends on the expansion of gasified LNG liquid. PBU-1, PBU-2 Build-up coils generating pressure are controlled by V-13 which is manual shutoff. Furthermore, Some cases can be automated by regulator or on-off valve. When the pressure of the tank decreases from standard level, On-Off Valve will open until it reaches the desired pressure. Finally, the On-Off Valve will be closed. The pressure change is involved with how much you use it, for example using LNG continuously.
Safety Device
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Safety Device consists of 2 sets of PRV (Pressure Relief Valve) .Each set will have 2 pairs working together which are set to the Maximum Allowable Working Pressure. If the pressure is over the setpoint, PRV will start opening. It will close until the pressure in the system is equal to the setpoint.
Instrument Device
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The gauge set consists of level gauge and pressure gauge:
- The level gauge is differential pressure type by using the difference of the pressure level of the low pressure and the high pressure. This differential pressure will push diaphragm mechanism to show the result.
- The pressure gauge is Bourdon Type. This type is measured at the cylinder head.
LNG outlet
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LNG can be used by opening the V-3 valve to distribute it through E-3. Normally, ISO container can be moved in any places and loaded back. However, filling LNG can also do in the same time but the tank pressure must be controlled stably
- Fill on V-2 (Top Fill ) by closing V-1 (Bottom Fill), which results from the top filling may decrease the tank pressure and fill slowly. Therefore, it relies on generating pressure from the pressure control circuit.
- In case of opening, filling on V-2 (Top Fill ) and V-1 (Bottom Fill) will continue as usual procedure by controlling the balance of both valves. However, there will be some amount of existing LNG during the filling that flows through V-3 to use in operation. This makes the amount of LNG decrease .Therefore, if taking into account the filling volume from LNG Truck, there should be a flow meter to measure the amount.
https://www.gmsthailand.com/product/lng-iso-tank-for-lng-station/ (https://www.gmsthailand.com/product/lng-iso-tank-for-lng-station/)
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Magnetic level indicator Aurora®
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Designed as an alternative and upgrade to traditional gauge devices, Magnetic Level Indicators (MLI) from Orion Instruments® are manufactured to provide accurate and reliable liquid level in a wide range of applications. Our MLI product line-manufactured globally at multiple facilities— requires minimum maintenance and eliminates common sight glass problems like vapor and liquid emission. Orion Instruments specializes in precision-engineered excellence and offers highly customized configurations and options for process environments, including those with extreme temperatures and pressures.
True Redundancy in a Single Chamber of Magnetic level indicator Aurora® .The Aurora® MLI combines Eclipse® Guided Wave Radar (GWR) and a float-actuated visual indicator to simultaneously provide both continuous and local level indication. So unique is the Orion Instruments ® dual redundancy within a singlechambered MLI that Aurora® has been granted a U.S. patent.
Technology of Magnetic level indicator Aurora®
Radar Transmitter
The Eclipse® transmitter continuously emits electromagnetic radar pulsesdirectly off the liquid surface.The on-board electronics provide a real-time level output, in addition to the external visual indicator operated by the Aurora® internal float.
Baffle Plate
The GWR probe area is separated from the freemoving float by a baffle plate.
Vertical Float
The custom float located inside the chamber is magnetically coupled to the visual indicator. The float rotates flags or moves a shuttle to visually indicate liquid tank level (as explained in more detail at right).
Visual Indication
The float positioned within the Aurora® chamber risesand falls according to levelchanges. The float contains an internal group of magnetsthat are “coupled” with magnets in the flags of the visual indicator. As the float moves, the flags rotate to expose the color of theiropposite side. The position where the flag’s color changes corresponds to a point on the measuring scale indicating true level. (The optional shuttle indicator moves parallel with the float to indicate level on the scale).
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Optimum Float Performance
Orion Instruments® floats are engineered to provide the world’s best MLI performance.The 360-degree vertical placement of the magnets assures proper coupling with the flag or shuttle of the indicator, even if the float is spinning in its chamber. The magnetic assembly creates a constant Gauss rating optimized to ensure reliable performance. Float magnets are designed to function at temperatures up to +537° C (+1000° F) for years of reliable service.Special float alloys are available.
Baffle Plate
The superb float performance within the Aurora® is due in part to an angled baffle plate mounted inside the chamber.The baffle plate ➀ partitions the GWR probe area ➁ from the float area ➂ and serves as a guide to ensure both smooth float travel and proper indicator operation. Perforations along the baffleplate equalize pressure and allow free media flow within the chamber. The probe area ➁ also acts as a gasbypass zone when flashing occurs. This helps in preventing damage to the float.
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Features of Magnetic level indicator Aurora®
Introduced in 1998, Eclipse® Guided Wave Radar (GWR) quickly ascended to its leading role in process level measurement. GWR is still favored throughout the industry for its easy setup, trouble-free operation, measurement accuracy, and immunity to changing process conditions.The Aurora® single chamber houses both the Eclipse® GWR probe and buoyancy float, with the former providing continuous measurement and the latter magnetically coupledto a visual indicator to provide local level indication. A flag-type indicator (or a moving shuttle) visually indicates liquid level. A variety of measurement scales and indicator flag colors are available.
Applications of Magnetic level indicator Aurora®
- Alkylation Tanks
- Blowdown Tanks
- Boiler Drums
- Condensation Tanks
- Deaerators
- Feedwater Heaters
- Flash Drums
- Gas Chillers
- Hot Wells
- Industrial Boilers
- Oil-Water Separators
- Propane Vessels
- Storage Tanks
- Surge Tanks
- Vacuum Towers
https://www.gmsthailand.com/product/magnetic-level-indicator-aurora/ (https://www.gmsthailand.com/product/magnetic-level-indicator-aurora/)
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Cameron Gate Valve with API6A standard
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Over the course of the last century, numerous gate valve design genres have been developed for use in the oil and gas industry. Designs that have commonly been used to control fluid through production trees and flowlines include expanding , wedge, and slab-style gate valves. Cameron engineers have selected the best-suited features for development and impletiontation into Cameron Gate Valve with API6A standard
Overview – Cameron Gate Valve with API6A standard
- Cameron designs and manufactures gate valves to API Spec 6A valves to help you meet the demands of land and offshore drilling and production, including
- large-bore completions
- extreme pressures and temperatures
- heavy oil
- sour service
- subsea applications.
Application of Cameron Gate Valve with API6A standard
The FLS gate valve is part of the F Series of valves, which have been supplied for production and drilling service since 1958. Many of the features of the FLS are common to our original Type F gate valve, such as
- full- and internally flushed bore and forged construction
- metal-to-metal sealing
- slab gate
- design simplicity.
In other areas such as seat seals and stem seals, the FLS design takes advantage of our latest technology in materials and seal design.
The Cameron FLS gate valve is widely recognized as a high-quality valve for severe applications, available in pressure ratings from 2,000 to 20,000 psi and bore sizes from 1 13/16 to 11 in. The FLS valve is our standard valve for critical requirements, including extreme sour and subsea applications. In addition, it can be fitted with a wide range of our actuators.
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FLS Gate valve : Product and Extreme service API6A slab-style gate valve Advantages
- Metal-to-metal sealing
- Reliability through simplicity of design
- Bidirectional sealing
- Stem backseat
- Nonelastomeric, spring-loaded, pressure-energized stem seal that requires no longitudinal preload or precise spaceout
- Innovative seat design
- Lip seals that perform several functions:
- Serving as added barrier against contaminants and debris
- Maintaining contact between the gate and seats, eliminating body cavity clearance while retaining downstream sealing function of the slab gate
- Enhancing sealing integrity at very low differential pressures, where low bearing stresses tend to limit the effectiveness of the metal-to-metal seal
- Qualification testing to API 6A, Annex F (PR-2) and Annex I (Class II)
- Optional torque multiplier
FL, FLS, and FLS-R gate valves, this chart represents typical valves for API material classes AA, BB, CC, DD, EE, FF, and HH (except FL) , Temperature ratings K, L, P, S, T, U, and V , Product specification levels 1, 2, 3, 3G, and 4.
Available product : Nominal Bore size vs Working pressure
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Reference Project
- PTTEP Siam : Yearly Contract Supply for API Gate valve in 2014-2015
- PTTEP Siam : Year Contract Supply for API Gate valve in 2021-2022
https://www.gmsthailand.com/product/cameron-gate-valve-with-api6a-standard/ (https://www.gmsthailand.com/product/cameron-gate-valve-with-api6a-standard/)
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SMITH Gaskets – Smith International Gulf Services
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SMITH Gaskets supplies a comprehensive range of oilfield products and services including industrial gaskets, advanced cutting services and hi-tech testing facilities.
A gasket is an elastomeric component that covers the point where two surfaces meet. They are often made of a range of materials, such as rubber, cork or paper, metal, copper, and foam. Because of its versatility, this adaptable element may be utilized for a variety of applications. These include anti-vibration, packaging, cleanliness, noise and sound reduction, and, perhaps most significantly, sealing. Gaskets are utilized in almost every industry, including food processing, petrochemicals, pharmaceuticals, water, and gas. Gasket materials are selected for their properties and capacity to endure a variety of conditions, including mining and deep-sea environments, as well as resistance to chemicals, alkaline acids, high temperatures, and pressure
How does a Gasket work?
A gasket must be squeezed enough to create a complete barrier that will form a pressure-tight seal and protect the contents within the seal in order for it to operate properly and seal away any leaks. Furthermore, gaskets protect moving components of an application by preventing them from rubbing against hard surfaces and causing friction. An elastomeric gasket is a component that creates a seal between two surfaces by sealing against the release or intake of both gases and liquids. They are excellent for filling defects and connecting two surfaces. Because a gasket will cover the gap between these two surfaces, it must be made of a material that is readily deformed and fills any imperfections. Compounds such as spiral wrapped gaskets are often made from a combination of metallic and softer filler material (flexible graphite). Metal gaskets must most of the time be squeezed at a greater tension in order to seal accurately. In certain instances, a sealant must be placed directly to the gasket to provide a leak-free seal.
Applications for Gaskets
A gasket is an important component in various production processes since they are available in a variety of specifications. Gasket material is selected for an installation based on properties like as resistance to chemicals, temperatures (or temperature variations), pressures, acids, gases, and, in certain cases, electromagnetic or electrical forces. Gaskets are widely used and may be found in automobiles, trains, aircraft, boats, electrical equipment, pumps, and a variety of other uses.
Industries that make use of gasket
A gasket material has the ability to withstand some of the most demanding conditions for industrial sealing goods, such as:
- Chemical synthesis
- Production of electricity
- Petrochemical and deep-sea exploration
- Oil and gas
- Mining
- Military
- Aerospace
- Filtration
- Food and Beverage
- Pharmaceutical
- Industries involved in sanitary processing
Gaskets may be manufactured using a variety of methods, depending on the material and application, including:
- Extrusion of rubber
- Cold bond splicing and hot vulcanized splicing
- Compression molding, injection molding, and transfer molding
- Slitting with precision
- Personalized die cutting
- Waterjet chopp
Gaskets and seals are used in almost every application and sector, including oil and gas, manufacturing and industrial uses, pulp and paper production, and agricultural equipment. Gaskets that have become worn or damaged are simple to repair. It is common practice to replace gaskets whenever the equipment is dismantled and rebuilt.
PRODUCT OF SMITH Gaskets
RING TYPE JOINTS
Ring joint gaskets are metallic sealing rings suitable for high pressure and high temperature applications and are fitted in ring groove type flanges.They are widely used in the Oil/Gas and Petrochemical industry, in valves and pipe-work. Choice of material may be determined to suit higher temperatures and aggressive media. They comply with ASME B16.20 standards and API spec 6A (where applicable).
The gasket hardness is carefully controlled and shall always be softer than the mating flanges to ensure a good seal and no damage to the flange surface (note: RTJ gaskets should not be re-used). All SMITH RTJ gaskets are manufactured from fully traceable materials and are stamped to the requirements of API 6A and ASME B16.20. DIN 50049 3.1 certification is supplied with all orders. The gaskets are machined to the required tolerances and surface finish using high quality CNC lathes. All soft iron and carbon steel RTJ gaskets are electroplated with zinc 0.0005″ thick in accordance with API specifications. Other non-standard styles of metal rings are also available like combination, IX, Delta and Lens to customer specifications.
1) TYPE R
R type ring joint gaskets are available in oval or octagonal cross section and manufactured in accordance to API 6A and ASME B16.20 to suit API 6B and ASME/ANSI B16.5 flanges. The oval ring fits the round and flat bottom ring groove flange, while the octagonal shape fits only the modern flat bottom groove flange.
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2) TYPE RX
The RX type RTJ gasket is manufactured in accordance to API 6A and ASME B16.20 to suit API 6B and ASME/ANSI B16.5 flanges. The RX is a pressure energized version of the R octagonal gasket and fits the R type flat bottomed groove.
The RX has an increased height and utilizes the internal system pressure to energize and improve the seal as internal pressure increases. Some RX sizes have a pressure relief hole to equalize pressure both sides of the sealing faces
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3) TYPE BX
The BX type RTJ gaskets are manufactured in accordance with API 6A and are suitable for use in high pressure API 6BX flanges.The gaskets form a metal-to-metal seal on assembly and the efficiency improves as internal pressure increases. All BX sizes have a pressure relief hole to equalize pressure across sealing faces.
- SRX and SBX RTJ gaskets to API 17D for subsea applications.
- IX rings for compact flanges
- Other non-standard styles of metal rings are also available like combination, IX, Delta and Lens to customer specifications
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SPIRAL WOUND GASKETS
Spiral Wound Gaskets are suitable for a wide range of operating conditions and can be adapted to suit almost all applications. The gaskets can seal fluid pressures up to 250 bar and temperature range of -200°C to in excess of 450°C.
THICKNESS : All RS and RSI gaskets for standard flanges have a 4.5mm thick sealing section of windings and filler material, with 3.2mm thick solid metal guide rings.
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https://www.gmsthailand.com/product/smith-gaskets-smith-international-gulf-services/ (https://www.gmsthailand.com/product/smith-gaskets-smith-international-gulf-services/)
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Tristar Best-in-Class Bolts and Nuts
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Tri-Star Group of Companies is the Leading Global Manufacturer and Supplier of Best in Class Bolts and Nuts, Cable Support Systems, Cathodic Protection Systems and Hydraulic Bolt Tensioning and Torquing Tools and Services to the worldwide Energy & Infrastructure sectors.
The Tri-Star Industries Group started business in the late 70’s, trading and manufacturing bolts and nuts. From humble beginnings, the Group has made significant progress to become a renowned manufacturer of fluoropolymer coated bolts and nuts, cable support systems, cathodic protection products & services and hydraulic bolt tensioning & torquing products & services for the Oil, Gas, Power, Petrochemical, Marine and Infrastructure Industries around the world.
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Overview – Tristar Bolts and Nuts
Fundamentals of Bolts and Nuts
In contrast to a screw, a bolt is typically accompanied with a nut and a washer in order to act as a fastener. As you tighten the nut, it forces the items you’re attaching towards one other, pushing the washer against one and tugging the bolt head against the other. Material, finish, size, and thread type must all be considered when matching a nut and washer to a bolt.
Materials and finishes for bolts, nuts, and washers
Steel is a popular material for nuts and bolts, however if they will be exposed to moisture or pressure-treated timber, which may corrode steel fasteners, ordinary steel fasteners need a corrosion-resistant coating. There are many popular DIY finishes.
- Zinc-plated bolts are corrosion resistant but should only be used inside. The finish is often thin, will not withstand the weather outside, and is not suitable for use with pressure-treated timber. Yellow zinc or yellow dichromate provides a layer that covers the zinc plating for increased corrosion resistance, but it does not offer protection for outdoor usage or when used with pressure-treated timber.
- Hot-dipped galvanized nuts, bolts, and washers are more corrosion resistant. These fasteners are designed for outdoor usage and are compatible with pressure-treated timber.
- Powder-coated paint finishes are intended for usage on the inside.
- Black phosphate is a coating that allows for excellent paint adherence.
- The corrosion resistance of epoxy and other coatings varies based on the kind of coating. Specific applications should be found in the product information.
- Stainless steel has excellent corrosion resistance. Stainless steel nuts, bolts, and washers are often used in exterior projects and when working with pressure-treated timber
- Because of their enhanced strength, hardened steel bolts are often utilized in automobile assembly.
Sizes of Bolts, Nuts, and Washers
Bolt, nut, and washer sizes will be specified in metric millimeters (mm) or standard or Society of Automotive Engineers (SAE) inches (in). A bolt’s diameter is typically the outer diameter of the threads. Compare the outside diameter of a bolt to the interior diameter of a nut and washer. Diameters of 1/4 inch and less are denoted by a # and a whole number in SAE nuts and bolts (a bolt with a main diameter of 3/16 inch is a #10 bolt). Smaller numbers represent smaller dimensions.
The distance between the end of the bolt and the underside of the bolt head, also known as the bearing surface, is typically indicated by length.
Thread Types for Bolts, Nuts, and Washers
Nuts and bolts are either coarsely or finely threaded. Match the threading of a nut to the threading of a bolt.
- The most prevalent are coarse-threaded nuts and bolts, which have greater space between the threads. They’ll be identified by a higher thread pitch. Because coarse-threaded bolts and nuts are less prone to get stuck or cross-threaded, they may be secured more rapidly.
- Fine-threaded nuts and bolts with lower thread pitches have fewer thread gaps, resulting in a tight, firm grip. Vibrations are less likely to dislodge a nut on a fine-threaded bolt but installing or removing the nut will take longer.
PRODUCT OF Tristar Bolts and Nuts
MASTERCOTE Fasteners
Studbolts
Studbolts are made from long length of bars. We sell studbolts and nuts plain, Mastercote PTFE coated, Cadmium, Zinc Nickel Plated, Galvanised and other types of coatings. Electroless Nickel plating is also available.Mastercote® fluoropolymer coated bolts and nuts were developed by us to initially service the oil and gas companies in Malaysia. We worked closely with them to derive a product that was both effective and cost efficient.Mastercote® coating is effective and more economical than using stainless, incoloy, titanium and dother exotic materials.Mastercote® bolting materials last much longer than any other fluoropolymer coatings. Mastercote® gives the best corrosion resistance, low friction with self-lubricating, non-galling properties – thus reducing make-up and break out torques. It is excellent for offshore and subsea installations.Mastercote® resists most acids and is unaffected even when exposed to hydrogen sulphide at 121ºC at 2,000psi.
- ASTM A193 – Imperial sizes 3/8 to 4” dia
- Metric sizes M12 tom M52
- ASTM A320 L7 – 1/2” to 4”
- ASTM A193 B16 – 1/2” to 4” dia
- ASTM A193/A320 B8 Class 2 & Class 1
- (SS304) 1/2” through to 2 3/4” dia
- ASTM A193/A320 B8M Class 2 & Class 1
- (SS316) 1/2” through to 2 3/4” dia
In-House Furnace
B7M/2HM and L7M/Gr 7M are produced in-house (tested and certified). These are then oiled, grit blasted, plated or Mastercote finished.
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- Subsea
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We are API 20E & 20F certified, specially to the subsea stringent requirements.
- Anchor, U-bolts
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We manufcture “U” bolts, pipe clamps and anchor bolts to clients’ specifications, in different thread forms (UNC, 8UN and or Metric) of carbon, stainless steel or any material grades. Available coating finishes: Zinc plate, Zinc-nickel plate, Cadmium plate, Xylan Fluorocarbon finishing coat. We also perform hot-dip and mechanical galvanizing in-house. Optional items: Clamps or ‘U’ bolts can be supplied with Neoprene sleeve, pad or strip or vulcanized rubber.
- Load Indicating Fasteners
Maxbolt Load Indicating Fastener
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Maxbolt load indicating fasteners continuously displays the amount of tension in a bolt or stud. They offer a simple method for accurate joint assembly, and it is the only product available (for most applications) that will continuously clamping force while the fastener is in service. Maxbolt load indicating fasteners are manufactured by inserting extremely accurate and durable load monitoring devices into high quality bolts and studs. Now, even inexperienced workers can complete complex assemblies with full assurance that fasteners are at the proper tension. Maxbolt also provide in-service monitoring which will warn users of any loosening in order to avoid premature wear, unnecessary downtime, or catastrophic failure.Our Maxbolt load indicating fasteners comes in various shapes and sizes. It can be manufactured from standard ANSI materials to exotic materials.
SPC4 Load Indicating Fasteners
The SPCA load indicating fastener allows user to install a bolted assembly with confidence. The user can constantly monitor the clamp load of any SPC4 bolted joint whether static or dynamic, by attaching a probe to the datum disc located on the end of the fastener and reading the value on a hand held battery powered digital monitor. Optional data gathering and storage of the bolted joint are available.The integrity of a bolted joint is jeopardized when fasteners lose their tension. This loss of clamping force begins during assembly due to elastic interactions and joint relaxation. Self-loosening continues when the joint is put in service due to vibrations, temperature changes, shocks, etc. The SPC4 joint allows the end-user to retighten only the bolts or studs that have lost their clamp load resulting in a tremendous saving of maintenance time, money and replacement parts. For a minimal investment, the SPC5 offers maximum joint integrity with optimum performance.
https://www.gmsthailand.com/product/tristar-best-in-class-bolts-and-nuts/ (https://www.gmsthailand.com/product/tristar-best-in-class-bolts-and-nuts/)
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MOZLEY FLUIDIZER – Settled solids removal system
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Schlumberger has a variety of solids and sand management systems that provide identifiable value in solving problems at the source,thus alleviating downstream issues and reducing operational concerns.
Overview – MOZLEY FLUIDIZER – Settled solids removal system
Fluidize many solid sizes settled in your process vessel
The MOZLEY FLUIDIZER settled solids removal system is a compact and efficient device used to generate flowing slurry from solids settled at the bottom of a tank or vessel. It is uniquely designed for online discharge of sand from vessels with minimum disruption to interface levels.
Free solids trapped in the system
The MOZLEY FLUIDIZER system uses a spray head that delivers fluidizing water at the right flow rate and in the right direction. Water flows up through the center of the solids remover and out through the nozzle at the top. It clears a 15-in cylinder with a 30°–40° cone around it, fluidizing and removing sand from the area. The fluidized sand flows out through the system annulus; more sand falls into the cleared area and is fluidized.
Special features:
- No moving parts
- Vertical or horizontal configuration
- Controlled injection of water
- Compact design easy to retrofit
Design custom solutions using various flow rates and configurations
An outlet route for the fluidized sand and solids provides flow resistance. This resistance ensures the sand will flow out of the vessel at a rate matching that of the incoming liquid, which prevents any change of levels in the vessel.
The MOZLEY FLUIDIZER system is available in three sizes, with slurry flow rates of 15, 35, and 66 galUS/min. We can help you select the correct flow for your process and equipment downstream of the flow.The solids removers can be mounted either individually, through vessel nozzles (4-in nozzles for optimal clearance), or manifolded together on a common header.
Application of MOZLEY FLUIDIZER – Settled solids removal system
The MOZLEY FLUIDIZER system uses a controlled injection of water into the sandcontaining vessel to generate a shallow yet broad zone of fluidized sand adjacent to the bottom of the vessel. Because no vortex is created, disturbance is localized to the area containing the deposited sand. This slurry flows toward the MOZLEY FLUIDIZER system, where it passes through an internal flow passage and is discharged from the system outlet. The system’s large zone of influence means that large volumes of sand can be removed by a single device, while the horizontal fluidization profile generates practically no disturbance in the liquid above. The MOZLEY FLUIDIZER system discharges a slurry of constant concentration until the sand level drops such that it is exposed when the slurry concentration will fall rapidly, giving a distinct cut-off point. The fluidizing water may be a separately pumped source or taken from the upstream process.
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MOZLEY FLUIDIZER system installed on a horizontal separator
https://www.gmsthailand.com/product/mozley-fluidizer-settled-solids-removal-system/ (https://www.gmsthailand.com/product/mozley-fluidizer-settled-solids-removal-system/)
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MOZLEY Wellhead Desander- Solids removal system
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Consisting of single or multiple cyclone inserts housed inside a vessel operating at the appropriate well head design pressure,MOZLEY Wellhead Desander solids removal systems are used at the production wellhead.These efficient units protect downstream equipment from mechanical damage and erosion. They also prevent partial blocking and settlement of sand in seperators that lead to a reduction in capacity.
Overview – MOZLEY Wellhead Desander- Solids removal system
- Eight times longer lifespan in aggressive multiphase well fluid environments
The MOZLEY Wellhead Desander Solids removal system provides unmatched performance and durability in one of the most difficult and important solids management applications: sand removal from wellhead fluids. To provide the most effective desanding and offer the best protection for equipment downstream of the wellhead, choosing the best hydrocylone configuration is key.
- Protect process equipment erosion and downtime
MOZLEY Wellhead Desander solids removal systems mitigate the effects of sand production, such as mechanical damage to equipment; erosion of pumps, valves, chokes, and flowlines; and reduction in separator capacity due to settlement of sand. The systems use a simple, compact design based on solid-liquid hydrocyclones to separate solids from both the gas and liquid components of well fluids. The hydrocyclone housings can be customized to handle high wellstream pressures and widely varying feed conditions.
- Choose fit-for-purpose solids removal at the wellhead
Selection of the hydrocyclone internals depends on the range of viscosities and specific gravities of the well fluids and the operating gas/liquid ratios. Proper selection ensures optimal performance throughout the operating ranges and provides equipment downstream of the desanding system with superior wear protection.
MOZLEY Wellhead Desander systems employ solid liners made of special silicon nitride ceramic material developed expressly for use in hydrocyclone liners. These liners last eight times longer than competitive alumina ceramic desanders or ceramic-coated hydrocyclones. This provides a reduction of downtime stemming from hydrocyclone wear and replacement, which lowers operating expense. Additionally, the liners are self-cleaning, and slugging of solids will not plug them, further reducing downtime and lowering opex.
- Use multiple small hydrocyclones for greater efficiency
The core of the system is the hydrocyclone liner. Use of extensively enhanced geometrical features and specifically selected construction materials maximizes performance and minimizes erosion in aggressive multiphase well fluid environments. Multiple hydrocyclones are typically installed within a pressure vessel, providing significantly greater efficiency and operating life compared with a large-diameter single hydrocyclone or ceramic-coated metal inserts.
These hydrocyclone clusters cope with the surges of gas and liquid flows much better than large-diameter single hydrocyclones, operating instantaneously to achieve solids separation. With a single hydrocyclone, any high-concentration slugs of solids can potentially block the inlet and underflow, preventing flow.
For less-demanding separation duties, a large-diameter single liner—typically 10-in diameter or greater—can be used. Packaged in a vessel, the single-liner design can reduce costs compared with multiple liners.
Application of MOZLEY Wellhead Desander- Solids removal system
The cyclone inserts of the MOZLEY Wellhead Desander system are specifically designed for each application using proprietary computer simulations. The silicon nitride ceramics developed expressly for used in the solid ceramic hydrocyclone liners deliver 8 times greater wear resistance, as compared with standard grades of ceramic liners or ceramic-coated hydrocyclones. Wellstream fluids enter the cyclone tangential inlet, which forces the mixture to spin and in turn causes the gas to disengage quickly. Both gas and liquids migrate toward the center of the cyclone, as a reduction in cyclone diameter accelerates the fluid while concurrently generating strong centrifugal forces. The gas and liquid flow then reverses and moves upward toward the overflow vortex finder. Solids are separated from the gas and liquid, forced toward the cyclone wall, where they travel down the length of the conical section of the cyclone in a spiral pattern to the solids outlet. The separated solids fall through into the accumulator vessel situated on the underflow of the wellhead desander, or a continuous hydrotransport device can be used. The accumulator vessel is periodically isolated and collected solids are flushed out. The wellhead desander itself remains online and operating while the accumulator is being cleaned.
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https://www.gmsthailand.com/product/mozley-wellhead-desander-solids-removal-system/ (https://www.gmsthailand.com/product/mozley-wellhead-desander-solids-removal-system/)
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MOZLEY Desanding Hydrocyclone
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MOZLEY Desanding Hydrocyclone as solids-water seperator efficiently and reliably removes solids from fluid streams. Fully packages designs are scalable to meet size requirements and can be fully automated to provide efficient,compact,solid-liquid seperation capabilities,including solids removal from produced water streams.
Overview – MOZLEY Desanding Hydrocyclone
- Remove solids from fluid streams with a range of properties
The MOZLEY Desanding Hydrocyclone solids-water separator is a versatile technology based on an optimized internal geometry that can accommodate a range of solid types and concentrations, fluid rates, pressures, and temperatures. This makes MOZLEY separators well-suited for the unique applications found in the oil and gas industry, including treatment of produced water, aquifer water, and deballast water; hydrocarbon desanding; and other sand cleaning operations.
Manufactured from abrasion-resistant ceramics that provide enhanced wear resistance and longer life, MOZLEY separators are designed to increase solids removal and reduce downstream issues while still allowing full production.
- Handle high flow rates with a compact system
Many hydrocyclones can be packed into a single vessel, resulting in a high unit flow rate. There are no moving parts in a vessel and operate continuously with minimum supervision and maintenance. Sand separation can be a fully automated with continuous or batch discharge of solids, with or without sand accumulation.
- Special features :
- Separation of 98% of particles from 3 to 108 um
- Flow rates from 25 to 100,000 bbl/d [3 to 11,924 m3/d] of water
- Pressure drop of 10 psi [0.07 MPa] from inlet to overflow outlet
- Customizable solutions for your solids challenges
The performance of a hydrocyclone depends on the pressure drop across the inlet and overflow outlet and the volume split to underflow. In general, a higher pressure drop yields a higher capacity and sharper separation.
Thus, the diameter of a hydrocyclone influences the size of solids removed. MOZLEY Desanding Hydrocyclone separators are available with individual hydrocyclone sizes ranging from 0.5 in to 30 in, with 2-in or 3-in ceramic desanding hydrocyclones standard for most applications.
The larger diameter, single-liner units offer high flow rates, but are not as efficient at removing smaller solids as narrower-diameter units that have multiple liners in a single vessel. Because of this, the diameter of hydrocyclone is selected based on the size of solids targeted for removal, with further optimization achieved by tailoring aspects such as inlet and outlet diameter. Construction material can also be matched to the solids expected in the system, for instance polyurethane for low-temperature applications, or extremely abrasion-resistant ceramic materials to address highly erosive solids.
Matching the most suitable hydrocyclone geometry with construction materials that can best address the characteristics of the process fluid and suspended solids creates a customized separation solution for most applications that will deliver reliability and efficiency over alternatives.
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Application of MOZLEY Desanding Hydrocyclone
The solids-water separator operates via pressure drop. Fluids are directed along an involute into the desander, which causes the fluid to spin. Strong centrifugal forces are generated by the spinning motion, causing the solids and liquid to separate. The centrifugal force generated in a hydrocyclone varies over its length and may reach a maximum of 2,000 g. Heavier solids are forced outward toward the wall of the hydrocyclone, and the lighter fluids migrate toward the center core. Because of geometric variables and flow patterns, the lighter fluids flow through the overflow, and the heavier solids are directed to the underflow. The result is a process with a retention time of typically 2 to 3 seconds. Hydrocyclones provide simple and effective means of achieving effective separation of solids and sand from produced and other water streams.For removing solids from a production system, desanders can be utilized either upstream or downstream of a production separator. The typical location is downstream of the production separator on the water outlet and upstream of the water level control valve. The majority of the sand is accumulated in the separator and will travel out with the water stream. This water outlet is located on the bottom center position of the separator to minimize solids buildup.
https://www.gmsthailand.com/product/mozley-desanding-hydrocyclone/ (https://www.gmsthailand.com/product/mozley-desanding-hydrocyclone/)
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CYCLOTECH SCARPA Cyclonic separation technologies
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CYCLOTECH SCARPA Cyclonic separation technologies removes sand and other solids from a production seperator on either a continous or batch basis.The modular system can be retrofitted into existing seperators as well as be incorporated into new-build plants.The SCARPA system can convert a three-phase seperator into a true four-phase seperator or a two-phase seperator into a true-phase seperator.The system was developed for topside and subsea production seperators.
Overview – CYCLOTECH SCARPA Cyclonic separation technologies
CYCLOTECH SCARPA Cyclonic separation technologies is one of the most important machines.Whether produced from the reservoir or introduced through well servicing, produced solids are a growing concern for upstream operators. If left uncontrolled, solids production can cause major flow assurance issues.
The keys to successful topside sand handling is flexibility in process design, technology selection, and Sand production is unpredictable, and the management solution is never universal. Sand management almost always includes factors such as accumulation, fluidization, transportation, cleaning, and disposal—all of which require careful consideration.
Our sand management technologies and sophisticated process design methodologies provide you with the tools to optimize sand management for every application, including multiphase, in-separator and liquid phase.
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Hydraulic conveyance of the CYCLOTECH SCARPA eductive sand jetting system can be directed toward one or more discharge outlet nozzles and then routed to a CYCLOTECH Sandscape system.
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- Sand receiving and cleaning systems
We offer a range of CYCLOTECH separation technologies that clean sand to such low oil concentrations that the cleaned material can be pretreated prior to shipment to shore or reinjected into the reservoir.
- CYCLOTECH SCARPA eductive sand jetting system
CYCLOTECH SCARPA eductive sand jetting system is a sand-conveying and -removing apparatus that removes sand and other solids from a production separator on a continuous or batch basis. The modular system can be used to retrofit existing separators or incorporated into new-build plants.
- Advantages
- Decreases pumped flow rate requirement
- Produces no effect on oil-water separation performance
- Maximizes separator water pad residence time
- Eliminates sand carryover to water and oil outlet streams
- Limits residue sand to less than 5% of total
- Reduces potential erosion and corrosion of separator
- Eases sand removal as it has less time to solidify in place
- Minimizes and controls sand concentrations in outlet pipe work, optimizing the availability and performance of downstream sand-handling equipment
- Limits the size and complexity of the downstream receiving equipment
- Minimizes risk of blockage
Application of CYCLOTECH SCARPA Cyclonic separation technologies
The SCARPA system creates a low-velocity flow that runs along the bottom of the separator through the use of specialized eductor nozzles. An eductor is an established solids-conveyance device that uses a small flow of high-pressure motive fluid to pump a higher-flow, lower-pressure fluid. The eductors’ format of suction from behind and discharge in front enables hydraulic balancing to generate a dynamic layer of water of comparatively low velocity along the bottom of a separator. Such hydraulic balancing prevents sand from settling and acts as an effective solids-transport system with minimal radial (vertical) disturbance.
This hydraulic conveyor can be directed toward one or more discharge outlet nozzles at the bottom of the separator and then routed to the suction of an external CYCLOTECH Sandscape* solids conveyance and concentration control system, which controls ejection of solids from the separator.
https://www.gmsthailand.com/product/cyclotech-scarpa-cyclonic-separation/ (https://www.gmsthailand.com/product/cyclotech-scarpa-cyclonic-separation/)
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CYCLOTECH WDC Series Wellhead desanding cyclone technologies
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CYCLOTECH WDC series wellhead desanding cyclone technologies can be applied to a wide range of gas/liquid ratios.Deploying WDC Series technologies enables determining the potential range of actual wellhead flowing conditions,designing the cyclone geometry to suit, and predecting seperation performance and cyclone pressure drop.
Overview – CYCLOTECH WDC Series Wellhead desanding cyclone technologies
- Customized new-generation solids separation technology
Schlumberger wellhead and production desanding cyclones represent a new generation of solids separation technology specifically designed for multiphase wellstreams. These custom-engineered technologies use the presence of the gas phase to improve rather than detract from separation performance.Therefore, CYCLOTECH WDC Series Wellhead desanding cyclone has an important role in this part.
Advantages
- Improved reliability through protecting chokes, flow lines, and manifolds from erosion as well as downstream equipment from erosion, corrosion, and blockage
- Reduced production separator sand jetting requirements
- Increased production above sand‑free rates
Application of CYCLOTECH WDC Series Wellhead desanding cyclone technologies
WDC Series technologies have no moving parts and separate solids from multiphase well streams by density differential, using only a small pressure drop across the cyclone. A solids-laden multiphase flow is directed into the inlet section of the cyclone via a tangential inlet port. This causes the fluid to spin at high velocity, creating a high-g radial acceleration field. The dense-phase solid particles are forced outward to the hydrocyclone inner wall. There, through internal hydrodynamic forces, solids are ejected from the apex of the cyclone while the rest of the multiphase flow exits via an axial port that is adjacent to the inlet. The separated solids are collected in a separate solids accumulator, which can be periodically purged on line without interrupting the hydrocyclone operation. This eliminates the need for duty or standby operation.
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https://www.gmsthailand.com/product/cyclotech-wdc-series-wellhead/ (https://www.gmsthailand.com/product/cyclotech-wdc-series-wellhead/)
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LNG Cylinder
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Our LNG Cylinder supplier is the leader of LNG Cylinder in China market where is the biggest market in the world.
Our LNG Cylinder certified by ECE R110 (Regulation No.110)
ตรงตามข้อกำหนดของกรมการขนส่งทางบก สำนักวิศวกรรรมยานยนตร์ ตามบันทึกข้อความวันที่8 มิถุนายน2564 ข้อ1.1
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Product Overview
- Double gas Cylinder Installed on the back
Size: 240L; 330L;450L/500L
Customer : FAW Jiefang (Changchun and Qingdao) , SAIC Iveco Hongyan
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- Extra Large Gas Cylinder with Aluminum Alloy Frame
Size: 750L; 995L;1000L;1350L
Customer : FAW Jiefang (Changchun and Qingdao), SAIC Iveco Hongyan Truck
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- Single gas cylinder installed by the side
Customer: FAW Jiefang(Changchun and Qingdao, SAIC Iveco Hongyan
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- Compressed air resevoirSize: 15L-45L Aluminum gas containerCustomer : FAW Jiefang Chengdu
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Workshop and Capacity
- Solid warehouse
- High efficiency
- Well organized workshop
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Cylinder Model Specification
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Inspections and Tests
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Our Customers
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Components
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How it works
ระบบการเติม
จะเติมเข้าผ่าน Connector J-1 LNG จะไหลผ่าน Check Valve C-1 เข้าสู่ถัง ซึ่งถ้าในระหว่างเติมมีความดันถังเพิ่มขึ้นมากกว่า 0.7 MPa ความดันจะถูกระบายออกไปผ่าน V-1 และ Connector J-2
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ระบบการสร้างแรงดันภายในถัง
เมื่อมีการใช้งาน LNG อย่างต่อเนื่องซึ่งเป็นผลให้ความดันภายในถังลดลง จะทำให้ไม่มีแรงดันเพียงพอต่อการดัน LNG เข้าสู่ระบบเชื้อเพลิง ระบบนี้จะทำงานโดยการใช้คุณสมบัติการขยายตัวจาก LNG เปลี่ยนสถานะเป็น NG โดยมีขั้นตอนคือ
การไหลของ LNG จะเริ่มเมื่อความดันในระบบมีค่าต่ำกว่าความดันที่ Regulator E-4 ตั้งไว้ (0.3-0.7 Mpa) LNG จะไหลผ่านวาล์ว V-3, E-2, E-4 ไปจนถึง PBC (Pressure Build-up coil) ซึ่งจะเป็นสถานะก๊าซ NG ไหลกลับเข้าไปในถังเพื่อเพิ่มแรงดัน
ระบบสร้างแรงดันจะหยุดทำงานต่อเมื่อแรงดันภายในถังกลับเข้ามาสู่สภาวะปกติโดยค่าแรงดันจะต้องมีค่ามากกว่าค่าความดันที่กำหนดไว้ของ Regulator E-4 ตั้งไว้ (0.3-0.7 Mpa)
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ระบบ ECONIMIZER
ในสภาวะการเก็บ LNG ในถัง จะมีการเปลี่ยนสถานะของก๊าซเหลว กลายเป็นไอก๊าซ อยู่ (Normal Evaporation) ซึ่งเมื่อแรงดันของถังสูงขึ้น จนเกินกว่าค่าแรงดันใช้งานที่ตั้งไว้ จะทำให้เกิดแรงดันส่วนเกินในถัง ระบบนี้จะทำงานโดยการนำแรงดันส่วนเกินนี้มาใช้งานก่อนระบบการจ่าย LNG ในสภาะวะปกติ โดยมีขั้นตอนคือ
การไหลของ NG จะเริ่มเมื่อความดันในระบบมีค่าสูงกว่าความดันที่ Regulator E-1 ตั้งไว้ (0.6-1.2 Mpa) NG จะไหลผ่านวาล์ว V-2, E-2 ไปจนถึง Pr (Vaporizer Cross flow type) และ E-3 ซึ่งจะเป็นสถานะก๊าซ NG ไหลผ่านไปยัง Buffer tank ซึ่งคือท่อจ่าย NG ในสภาวะปกติจนถึงระบบเครื่องยนต์
ระบบ Economizer จะหยุดทำงานต่อเมื่อแรงดันภายในถังกลับเข้ามาสู่สภาวะปกติโดยค่าแรงดันจะต้องมีค่าต่ำกว่าค่าความดันที่กำหนดไว้ของ Regulator E1 ตั้งไว้ (0.6-1.2 Mpa)
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ระบบการจ่าย LNG
ในสภาวะการเก็บ LNG ในถัง ที่มีสถานะปกติ LNG จะไหลผ่านวาล์ว C-2 ,V-2, E-2 ไปจนถึง Pr (Vaporizer Cross flow type) ซึ่งจะเป็นสถานะก๊าซ NG ไหลผ่านไปยัง E-3 และ Buffer tank ซึ่งคือท่อจ่าย NG ในสภาวะปกติ จ่ายไปยังเครื่องยนต์
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https://www.gmsthailand.com/product/lng-cylinder-for-truck (https://www.gmsthailand.com/product/lng-cylinder-for-truck)
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CYCLOTECH MC Series desanding hydrocyclone technologies
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CYCLOTECH MC Series desanding hydrocyclone technologies remove solids from produced water,seawater, and liquid hydrocarbon streams to meet the demanding environmental and physical requirements of the upstream oil and gas industry. The technologies’ mosr common applications are for produced water systems,protection of downstream equipment,and reinjection systems.
Overview – CYCLOTECH MC Series desanding hydrocyclone technologies
CYCLOTECH* MC Series* desanding hydrocyclone technologies remove solids from produced water, seawater, and liquid hydrocarbon streams to meet the demanding environmental and physical requirements of the upstream oil and gas industry. The technologies’ most common applications are for produced water systems, protection of downstream equipment, and reinjection systems.
ADVANTAGES
- Broad range of solids sizes managed from 2 um to 15 mm
- No moving parts for enhanced reliability
- No need for duty or standby operation
- High sand removal efficiency regardless of hydrocyclone diameter
- Robust makeup materials stand up to erosion
Application of CYCLOTECH MC Series desanding hydrocyclone technologies
MC Series technologies have no moving parts and achieve solid-liquid separation using a pressure drop across the unit. Slurry is directed into the inlet section of the liner via a tangential inlet port. This, together with a narrow cyclone diameter, causes the fluid to spin at high velocity, creating a high-g radial acceleration field. The denser-phase solid particles are forced outward to the hydrocyclone inner wall. Here, through internal hydrodynamic forces, the solids are ejected from the apex of the cyclone while the liquid exits via an axial port adjacent to the inlet. The separated solids are collected in a solids accumulator, which can be periodically purged on line without interruption to the hydrocyclone operation. This purging eliminates the need for duty or standby operation.
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Schlumberger produced water and sand management technologies provide compact, targeted, robust, and flexible solutions that meet discharge requirements for customers’ specific applications.
https://www.gmsthailand.com/product/cyclotech-mc-series-desanding-hydrocyclone/ (https://www.gmsthailand.com/product/cyclotech-mc-series-desanding-hydrocyclone/)
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WELSPUN ERW/HFI
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WCL currently offers one stop solution in line pipes with a capacity to manufacture Longitudinal (LSAW), Spiral (HSAW) and HFERW / HFI (ERW) pipes. The company additionally offers coating, bending and double jointing facilities, thereby giving a 360-degree pipe solution to its customers.
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Technical Excellence
- 90 m long Looper Tunnel/ Accumulator with 180 meters strip length capacity
- 600 kW solid state High Frequency Welder with on-line monitoring and data recording
- 1500 kW Seam Normalizing Unit comprising 3×500 kW Induction Units
- On-line Internal Bead Scarfing with CCTV monitoring
- State-of-the-art ROTO UT System (Immersion Testing) for Weld, HAZ and Pipe Body (100% coverage)
https://www.gmsthailand.com/product/erw-hfi/ (https://www.gmsthailand.com/product/erw-hfi/)
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WELSPUN LSAW (Longditudinal)
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WCL currently offers one stop solution in line pipes with a capacity to manufacture Longitudinal (LSAW), Spiral (HSAW) and HFERW / HFI (ERW) pipes. The company additionally offers coating, bending and double jointing facilities, thereby giving a 360-degree pipe solution to its customers.
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Technnological Excellence
- High thickness rolling capabilities
- Auto Pipe Dimension Measurement System (APDMS)
- Online Plate UT System
- State-of the-art, high capacity, PLC governed Mechanical Expander
- High capacity (650 bar) Hydro Testing Machine
- State-of-the-art Auto UT from GE Inspection Technology (2 lines)
https://www.gmsthailand.com/product/lsaw/ (https://www.gmsthailand.com/product/lsaw/)
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WELSPUN Coating
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WCL currently offers one stop solution in line pipes with a capacity to manufacture Longitudinal (LSAW), Spiral (HSAW) and HFERW / HFI (ERW) pipes. The company additionally offers coating, bending and double jointing facilities, thereby giving a 360-degree pipe solution to its customers.
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Technological Excellence
- Mechanized Epoxy Powder Feeding System
- On-line monitoring and recording by Optical Pyrometer and Chart Recorder
- Automatic OD Coating Stripping Line (offline)
- Environmental friendly High Volume Bag Filters with Dust emission Levels less than 20mg/Nm3
- 4000kW High-Frequency Induction Heat System
- 125 Feet Long Cooling Tunnel with Stainless Steel Troughs designed for uniform laminar flow of water
- Efficient Curing Chamber at Internal Lining with mechanized feeding to External Coating Line
External and Internal Pipe Coating
Coating Product Range
- 3 Layer Polyethylene / Polypropylene Coating.
Complying ISO 21809-1, DIN 30670-12, DIN 30678-13, CSA Z.245.21-Series-14, NF49 710, NF49 711 and Client Specification
- Fusion Bonded Epoxy (Single / Dual layer) coating.
Complying CSA Z 245.20 Series -14, NACE SP 0394-13, ISO 21809-2 and Client Specification
- Internal Flow Epoxy Coating.
Complying API RP5L 2, ISO 15741 and AWWA C210
- External and Internal Bend Coating.
Complying EN 10290, API RP5L 2, ISO 15741 , AWWA C210 and Client Specification
- Concrete Weight Coating
Complying ISO 21809-5, AWWA C 205, DNV-OS-F101 and Client Specification'
https://www.gmsthailand.com/product/welspuncoating/ (https://www.gmsthailand.com/product/welspuncoating/)
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WELSPUN HSAW (Spiral)
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WCL currently offers one stop solution in line pipes with a capacity to manufacture Longitudinal (LSAW), Spiral (HSAW) and HFERW / HFI (ERW) pipes. The company additionally offers coating, bending and double jointing facilities, thereby giving a 360-degree pipe solution to its customers.
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Technological Excellence
- 240 meters long, Non-stop Coil Feeding Line with on-line Transverse Milling and Flying Cross Seam Welding System
- Max Coil Width: 2,800 mm for high productivity
- Heavy duty, 45 MT capacity De-coiler
- Digital pulse GMAW Welding System equipped with Automatic Lase Control for spatter free welding
- Hight definition, Digital Control Power Wave SAW System with 3-axis Laser Seam Tracking
https://www.gmsthailand.com/product/hsaw-spiral/ (https://www.gmsthailand.com/product/hsaw-spiral/)
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WELSPUN Hot Pulled Induction Bends
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WCL currently offers one stop solution in line pipes with a capacity to manufacture Longitudinal (LSAW), Spiral (HSAW) and HFERW / HFI (ERW) pipes. The company additionally offers coating, bending and double jointing facilities, thereby giving a 360-degree pipe solution to its customers.
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Tecnological Excellence
- In-house Mother Pipe manufacturin
- Controleed alloy design from steel making stage for mother pipes
- 500 kW and 1500 kW Induction Heating capacity
- Minimum wall thining and oveality
- Precise bending redius and angle
https://www.gmsthailand.com/product/hot-pulled-induction-bends/ (https://www.gmsthailand.com/product/hot-pulled-induction-bends/)
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Welpsun Pipeline with Engineering Excellence
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Welspun Corp Limited (WCL) is one of world’s-leading welded line pipe manufacturer, and the flagship company of the Welspun Group. Welpsun Pipeline , we believe in acquiring talent, developing skills, engaging individuals in multiple projects, and providing them with world-class experience and exposure, while keeping our core values at the crux of these activities.
We’re a team of nearly 4,000+ people across the world, focused on building a culture of ‘Engineering Excellence’in our Welpsun Pipeline
Over the last two decades, our innovative approach and, technical capabilities have helped us deliver some of the path-breaking Welpsun Pipeline projects across the world.
With over $1.2 billion of annual revenue, Welspun Corp is a true Indian multinational, operating across multiple geographies. We share a close relationship with our customers, and are the providers of choice for some of the largest players in the global oil and gas industry.
Welpsun Pipeline Capacitied and Capabilities
ERW
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Technical Excellence
- 90 m long Looper Tunnel/ Accumulator with 180 meters strip length capacity
- 600 kW solid state High Frequency Welder with on-line monitoring and data recording
- 1500 kW Seam Normalizing Unit comprising 3×500 kW Induction Units
- On-line Internal Bead Scarfing with CCTV monitoring
- State-of-the-art ROTO UT System (Immersion Testing) for Weld, HAZ and Pipe Body (100% coverage)
LONGITUDINAL SUBMERGED ARC WELDED (LSAW)
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Dahej: 3,50,000 MTPA
Anjar: 3,50,000 MTPA
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Technnological Excellence
- High thickness rolling capabilities
- Auto Pipe Dimension Measurement System (APDMS)
- Online Plate UT System
- State-of the-art, high capacity, PLC governed Mechanical Expander
- High capacity (650 bar) Hydro Testing Machine
- State-of-the-art Auto UT from GE Inspection Technology (2 lines)
HELICALLY SUBMERGED ARC WELDED (H-SAW)
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Anjar: 3,80,000 MTPA
Dahej: 50,000 MTPA
Mandya: 1,50,000 MTPA
Bhopal: 1,75,000 MTPA
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Award
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https://www.gmsthailand.com/product/welpsun-pipeline-with-engineering-excellence (https://www.gmsthailand.com/product/welpsun-pipeline-with-engineering-excellence)
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Flowserve Serck Audco Plug Valve for oil&gas isolation
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For the biggest challenges of fluid motion control, customers worldwide rely on the engineering, project management and service expertise of . We Flowserve Plug Valve deliver more than the most complete portfolio of reliable valves, pumps and seals available.
Our global team of more than 18,000 employees in 55 countries can put together the total solution-from project planning to lifecycle maintenance programs to some of the most proven technology on the planet by Flowserve Plug Valve. All so you can get more from your capital investment. Exceed your operational goals. And always come through, when failure is not an option.
Serck Audco was founded in 1869. Their long-established reputation is maintained by modern valve design and manufacturing techniques. Supplied and serviced around the world, Serck Audco products are used in industries as diverse as oil and gas, mining, food and chemical processing.
Why Select a Flowserve Plug Valve?
- PRESSURE BALANCED PLUG VALVES
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Large seating area enhances the Super-H resistance to erosion.
The wide area maximizes the effectiveness of sealant, so that any unlikely seat damage can solve injecting Serck Audco Sealant, restoring the valve zero leakage bubble tight shut-off capabilities without the need of seats replacement.
Moreover, Sealant can inject with the valve in any position and also under pressure, making the valve in-line maintainable.
- BALL VALVES
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BALL VALVES
The thin seating area can be damaged by the erosion action of the media and the particles contained in it.
Difference between Sealant for Plug Valve and Sealant for Ball Valve
Sealants for Ball Valves valve generally designs to stop leakages on damaged ball valves. To achieve this and since Ball Valves have thin seating areas, sealants are thicker and include a higher percentage of solid fillers in an effort to plug seat damages and not be washed away by pressure.
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Difference between Sealant for Plug Valve and Sealant for Ball Valve 1
Futhermore, Sealants for Flowserve Plug Valve designs to provide general lubrication and bubble tight sealing performance. Since plug valves have relatively wide seating areas, sealants can be thinner and still provide zero leakage over several operations.
Using a Ball Valve sealant on a Plug Valve is not recommended. Moreover,The thicker nature (and high percentage of solid fillers) of a Ball Valve sealant will increase operating torques due to the wide contact area between plug and body and even lead to valve jamming if the sealant dries up.
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Difference between Sealant for Plug Valve and Sealant for Ball Valve 2
Flowserve Plug Valve Products
1) Lubricated Plug Valves – SUPER H
BRAND: Serck Audco
The Super-H Lubricated Plug Valve is a rugged, pressure balanced plug valve designed for demanding oil and gas isolation applications where bubble tight shut-off and reliable operation are critically important.
Super-H Design
Basic design advantages of Flowserve Plug Valve such as metal-to-metal seats and a wide seating area, along with competitive pricing, have made plug valves the product of choice when the valve operates in a difficult or dirty service and/or needs to open against full differential pressure. The robust metal-to-metal seats ensure long valve life on any service, even in presence of solid particles in the line media.
Features and Benefits
Benefits
- Certainty of zero leakage sealing down the line, even with damaged metal seats.
- Certainty of operation with low and consistent torque which is stable over long periods of time.
- Minimal maintenance regime.
- Full in-line maintainability even under full pressure and without any need of shut down.
- Assured sealing to atmosphere.
How It Is Achieved
- Precise seat mating procedures.
- Effective sealant injection system combined with wide seating areas.
- Pressure balanced plug as standard, with option of Protected Pressure balance®
- Super LoMu Anti Friction Treatment on plug and stem.
- Precise factory set plug loading
- Provision for sealant injection for the seats
- Provision for stem packing re-injection
- Independent stem sealing design that can meet stringent fugitive emissions requirements.
- All pressure seals in fire safe metal or graphite.
Design Range
- Super-H valves are available in Regular, Short or Venturi, Pattern, in accordance with API 6D, API 599 and BS 5353. The different patterns vary in regard to face-to-face dimension and port area for a given size of valve.
- Size Range:
- DN 15 to 1050
- NPS ½ to 42
- Pressure Class Range:
- PN 20 to 420
- Class 150 to 2500
- API 2000 to 10000
Standard
- API 6D – Specification for pipeline valves
- API 6A – Specification for wellhead equipment
- ISO 14313 – Petroleum and natural gas industries-Pipeline valves
- ISO 10423 – Petroleum and natural gas industries-Wellhead equipment
- API 599 – Metal plug valves – flanged, threaded and welding ends
- BS 5353 – Specification for steel plug valves
- ANSI B16.10 & BS 2080. – Face-to-face and end-to-end dimensions
Sample Applications
- Bypass Equalizing Valve : To resist the erosion caused by full differential pressure openings on a transmission line, it will seal to protect the main line valve
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Bypass Equalizing Valves
- High Pressure Gas Isolation : Bubble tight shut-off on one of the more searching medias
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High Pressure Gas Isolation
- Underground Storage : Protected metal seating to resist impurities and give zero leakage even on the highest pressures
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Underground Storage
- Slurry Isolation Extremely abrasive services, a robust valve with no cavities
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Reference
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https://www.gmsthailand.com/product/flowserve-serck-audco-plug-valve-for-oilgas-isolation/ (https://www.gmsthailand.com/product/flowserve-serck-audco-plug-valve-for-oilgas-isolation/)
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TEG1120 100watt (Class1, Div2 or Class1, Div 1)
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The Model 1120 Thermoelectric Generator is Class 1, Div 2 or Class 1, Div 1 hazardous area rated. With no moving parts it is a reliable, low maintenance source of DC electrical power for any application where regular utilities are unavailable or unreliable.
KEY DESIGN FEATURES OF TEG1120 :
- Automatic Spark Ignition (SI)
- Automatic Fuel Shut-Off (SO)
- Fuel Filter
- Low Voltage Alarm Contacts (VSR)
- Volt & Amp Meter
- Reverse Current Protection
- Flame Arrestor
- CSA Certification (Class 1, Div 2 Group D, Temp T3)
OPTIONAL FEATURES OF TEG1120 :
- FM Certification (Class 1, Div 1, Temp T3)
- 316 SS Regulator & Fuel Valve
- Cathodic Protection Interface Panel
- Pole Mount or Bench Stand
- Intake Air Filter
ANOTHER FEATURES
Power Specifications
Power Rating at 20ºC : 110 Watts @ 6.7 Volts, 100 Watts @ 12 Volts,100 Watts @ 24 Volts, 100 Watts @ 48 Volts
Electrical
Output Adjustment Range: 6.7 V up to 11 Volts,12 V 12–18 Volts,24 V 24–30 Volts,48 V 48–60 Volts
Fuel Requirements
Natural Gas: 8.8m3/day (311 Sft3/day), 1000 BTU/Sft3 (37.7 MJ/Sm3) ,gas max 115 mg/Sm3(~170 ppmw) ,H2S max 120 mg/Sm3, H2O max 1% free O2
Environmental
Ambient Operating Temperature: Max. +45ºC (115ºF) , Min. -20ºC (-4ºF)
Construction
Materials: Cabinet : 316 Stainless Steel (SS) / Cooling Type: Natural Convection / Fuel System: Aluminum & Stainless Steel
https://www.gmsthailand.com/product/teg1120-100watt/ (https://www.gmsthailand.com/product/teg1120-100watt/)
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TEG1500 500watt (Class1,Div2)
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The Model 1500 Thermoelectric Generator (TEG1500) is Class 1, Div 2 hazardous area rated.
The Model 1500 Thermoelectric Generator is Class 1, Div 2 hazardous area rated. With no moving parts, it is a reliable, low maintenance source of DC electrical power for any application where regular utilities are unavailable or unreliable.
KEY DESIGN FEATURES OF TEG1500
- Automatic Spark Ignition (SI)
- Automatic Fuel Shut-Off (SO)
- Fuel Filter
- Low Voltage Alarm Contacts (VSR)
- CSA Certification
- Reverse Current Protection
- Class 1, Div 2, Group D, Temp T3
- Volt & Amp Meter
- Flame Arrestor
OTHER FEATURES OF TEG1500
Power Specifications
Power Rating at 20ºC : 500 Watts @ 24 Volts
Electrical
Output Adjustment Range : 24 V 24–30 Volts
Fuel Requirements
Natural Gas: 48.0m3/day (1695 Sft3/day) ,1000 BTU/Sft3(37.7 MJ/Sm3) , gas max 115 mg/Sm3(~170 ppmw) ,
H2S max 120 mg/Sm3 , H2O max 1% free O2
Environmental
Ambient Operating Temperature: Max. +45ºC (115ºF) , Min. -40ºC (-40ºF)
Construction
Materials: Cabinet : 316 Stainless Steel (SS) , Cooling Type : Natural Convection , Fuel System : Aluminum & Stainless Steel
https://www.gmsthailand.com/product/teg1500-500watt/ (https://www.gmsthailand.com/product/teg1500-500watt/)
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TEG 8550 500watt
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The Model 8550 Thermoelectric Generator ( TEG 8550 ) contains no moving parts.
The Model 8550 Thermoelectric Generator contains no moving parts. It is a reliable, low-maintenance source of DC electrical power for any application where regular utilities are unavailable or unreliable.
KEY DESIGN FEATURES OF TEG 8550
- Automatic Spark Ignition (SI)
- Automatic Fuel Shut-Off (SO)
- Fuel Filter
- Low Voltage Alarm Contacts (VSR)
- Reverse Current Protection
OPTIONAL FEATURES OF TEG 8550
- Corrosive Environmental Fuel System
- Bench Stand
- Ethylene Fueled
- Operation Over 4000m Elevation
- Cathodic Protection Interface
OTHER FEATURES
Power Specifications
Power Rating at 20ºC : 480 Watts @ 12 Volts , 550 Watts @ 24 Volts, 480 Watts @ 48 Volts
Electrical
Output Adjustment Range : 12 V 11.4–12.6 Volts , 24 V 24–30 Volts, 48 V 47–57 Volts
Fuel Requirements
Natural Gas: 48.0m3/day (1695 Sft3/day) ,1000 BTU/Sft3 (37.7 MJ/Sm3), gas max 115 mg/Sm3 (~170 ppmw) , H2S max 120 mg/Sm3
H2O max 1% free O2
Environmental
Ambient Operating Temperature: Max. +45ºC (115ºF) , Min. -40ºC (-40ºF)
Construction
Materials: Cabinet: 304 Stainless Steel (SS) , Cooling Type: Natural Convection , Fuel System: Brass, Aluminum & Stainless Steel
https://www.gmsthailand.com/product/teg-8550-500watt/ (https://www.gmsthailand.com/product/teg-8550-500watt/)
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Honey Well Product Sensing & IOT
Honey Well Product
Sensing & IOT
Honeywell Store is the leading brand products. There are many types of products such as Honeywell Switches & Controls ,Honeywell Sensors etc.
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https://www.gmsthailand.com/category/other-part-supply/honeywell-other-part-supply/sensing-iot/ (https://www.gmsthailand.com/category/other-part-supply/honeywell-other-part-supply/sensing-iot/)
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Global Solar Hybrid Power Systems
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Thermoelectric (TEG) and M-Series Generators are the perfect companion to solar (PV) power systems. Global Solar Hybrid systems face challenges including available daily sunlight, extreme temperatures, seasonal shading and debris covered solar panels (snow, dirt/dust, sand, etc.). When you combine the power of solar with a TEG or M-Series generator the result is the most reliable off-grid power system available on the market today.
We make Global Solar Hybrid Power Systems for the world.
There are times when battery-based solar systems fail to provide reliable power to critical systems, including :
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Operational challenges for solar only systems
- Daily available sunlight: no sun = no power.
- Extreme cold: during winter months, solar systems fail due to extreme temperatures, snow covered solar panels, and reduced daily sunlight.
These conditions prevent batteries from maintaining a consistent or minimal charge, often resulting in costly replacement due to failure.
- Extreme heat: contrary to popular belief, batteries do not work well in extreme heat. In fact, extreme heat damages and degrades batteryperformance making frequent replacement the only option. Cost of batteries, along with cost of site visits, becomes a burden.
- The solution: by incorporating a thermoelectric generator (TEG) to your site, you can eliminate system downtime while saving on operational
costs (site visits, maintenance, battery replacement) in both the short- and long-term.
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Global Solar Hybrid Advantage
- Most reliable remote power solution available on the market today
- Lowest operating expense on the market
- Commercially available fuel vs. imported competitor fuels
- Low emissions
- Optimizes and extends battery life
- Minimal annual maintenance
Features & Benefits of Global Solar Hybrid Power Systems :
- 50–500 watt systems available.
- 12V, 24V or 48V output.
- Lowest operational cost on the market.
- Optimizes & extends battery life.
- Minimizes fuel consumption.
- Small environmental footprint.
- Remote monitoring.
How it works
Solar Hybrid systems combine photovoltaic (PV) panels and Thermoelectric (TEG) or M-Series Generators to decrease the size and cost of the PV and battery requirements, while keeping system reliability at the highest possible level.
By incorporating a TEG or M-Series generator to your site, you can eliminate system downtime while saving on operational costs (site visits, maintenance, battery replacement) in both the short- and long-term.
The Global Power Technologies (GPT) Solar Hybrid Controller monitors the battery bank’s state of charge and starts the generator when the battery becomes too low. When the PV array is delivering enough energy for the battery to exceed the minimum state of charge to the load, the generator can turn itself off until required again.
The chart below illustrates performance of a Solar-only system vs. TEG Hybrid system during a typical solar year.
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https://www.gmsthailand.com/product/global-solar-hybrid-power-systems/ (https://www.gmsthailand.com/product/global-solar-hybrid-power-systems/)
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Processing and Separation technologies have several products such as Gas processing and treatment, Integrated surface production systems, Oil treatment technology , Solid management and Water treatment .
https://www.gmsthailand.com/category/processing-and-seperation/ (https://www.gmsthailand.com/category/processing-and-seperation/)
Gas Processing & Treatment
Gas Processing & Treatment contains inherent impurities which not only accelerate the pipe corrosion and transmission regulators but also reduce the heating gas as well. These contaminants must be removed before the gas flows to the processing plant . This includes our efficient services such as High-Efficiency phase seperation internal ,Cyclotech B Series deoiling hydrocyclone,PUREMEG Monoethylene glycol (MEG) reclamation and regeneration system ,Advanced Apura Gas Separation Membrane,Amine gas treating system with field-proven, Glycol Dehydration Systems for water removal
Our sophisticated experts offer a wide range of services,including conceptual design project ,implementation, pre-commissioning, commissioning, operation, remote monitoring and technical support.
https://www.gmsthailand.com/category/processing-and-seperation/gas-processing-treatment/ (https://www.gmsthailand.com/category/processing-and-seperation/gas-processing-treatment/)
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Integrated Surface
Integrated Surface Production Systemis a new innovative system built on this technology is a proprietary backwashing system used in oily wastewater and production and processing water. A regenerative agent coated with a patented polymer technology. The new generation media provides economically sustainable treatment for oil and suspended solids removal. There are several systems: Advanced Regenerative Water Treatment Media, Advanced Media Polisher/ Oil-in-water polishing filters, CYNARA Acid Gas Removal Membrane Systems,MYCELX Polisher Oil. -In-Water Polishing Filter, Early Production Systems
https://www.gmsthailand.com/category/processing-and-seperation/integrated-surface-production-system/ (https://www.gmsthailand.com/category/processing-and-seperation/integrated-surface-production-system/)
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Oil Treatment Technologies
Our crude oil treatment technologies include multiphase separation systems, dehydration and desalting electrostatic treaters, and distillate treaters. We use these technologies — perfected over many decades —to provide solutions ranging from single-stage product applications to complete oil treatments to ensure your oil is cost-effectively delivered to specification.
We can use our industry-leading technologies to optimize a processing facility tailored to your requirements.
Our experts can also help you identify upgrade opportunities for your existing facilities that will boost production and provide an immediate return on investment.
https://www.gmsthailand.com/category/processing-and-seperation/oil-treatment/ (https://www.gmsthailand.com/category/processing-and-seperation/oil-treatment/)
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Solid management throughout your gas and liquid process
Solid management throughout your gas and liquid process Knowing both the nature of solids in the liquid used in production and when they will occur is a key advantage in designing separation and handling systems. By using trait analysis and test insights well. We can help you build custom solids solutions from an array of efficient separation, transport and treatment technologies. This reduces production downtime. which technology The solids handling industry includes MOZLEY Wellhead Desander- Solids removal system, MOZLEY Wellhead Desander- Solids removal system, MOZLEY Desanding Hydrocyclone, CYCLOTECH SCARPA Cyclonic separation technologies, CYCLOTECH WDC Series Wellhead desanding cyclone technologies, CYCLOTECH. MC Series desanding hydrocyclone technologies
solid erosion equipment Foul and plug system components and is the driving force of overall production efficiency Cleverly designing and implementing a system that is suitable for the purpose can reduce both costs and expenses. while meeting your specific needs.
Our reliable, maintenance-free technology portfolio can help you mitigate the negative effects of solids in any process. of your production process while supporting solid filling and operating conditions such as flow rate, pressure and temperature.
https://www.gmsthailand.com/category/processing-and-seperation/solids-management/ (https://www.gmsthailand.com/category/processing-and-seperation/solids-management/)
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Water Treatment
Processing and separation technologies such as high potential water treatment excellent technologies such as Sulfate Removal System – Effective treatment of seawater for injection , Effective SEA-SCREEN Coarse Strainer, Polymem UF Seawater Ultrafiltration System ,UNICEL Vertical IGF – Induced-Gas Flotation Unit,Reverse Osmosis Systems for removing dissolved salts. from seawater, CYCLOTECH Cyclonic Separation Technologies,EPCON Dual Compact Flotation Unit (CFU), which is suitable for oil and gas industry.
https://www.gmsthailand.com/category/processing-and-seperation/water-treatment/ (https://www.gmsthailand.com/category/processing-and-seperation/water-treatment/)
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Tristar
Tristar Best in Class Bolts and Nuts started business in the late 70s, Tri-Star Industries Group has made a great progress and become a well-known manufacturer of fluoropolymer coated bolts and nuts. Also, Tristar is a cable support system Hydraulic and torque bolt tensioning products and services for the global oil, gas, power, petrochemical, marine and infrastructure industries.
https://www.gmsthailand.com/category/tristar/ (https://www.gmsthailand.com/category/tristar/)
(https://www.gmsthailand.com/wp-content/uploads/2021/09/Tristar-Bolts-and-Nuts-315x315.jpg)
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Global Power Technologies (GPT)
Global
In 1975, the founders of Global Power Technologies (GPT), an entrepreneurial group in Alberta, Canada, began manufacturing and developing thermoelectric generators (TEGs) for commercial use throughout the country. The examples of products are TEG1120 100watt (Class1, Div2 or Class1, Div 1) , TEG1500 500watt (Class1,Div2) , TEG 8550 500watt.
https://www.gmsthailand.com/category/global/ (https://www.gmsthailand.com/category/global/)
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Liquefied Natural Gas (LNG) equipments
LNG equipments
Liquefied Natural Gas (LNG) is a natural gas that has been converted from gas to liquid. By reducing the temperature to about -160 degrees Celsius, there are many types of equipment involved such as LNG transportation , Cryogenic Liquid Semi-trailer ,LNG Station LNG storage tank for Permanent LNG station,LNG as truck fuel, LNG Vehicle gas Supply System with highest standard and application.
https://www.gmsthailand.com/category/lng/ (https://www.gmsthailand.com/category/lng/)
(https://www.gmsthailand.com/wp-content/uploads/2021/11/Small-Scale-LNG-equipment-01-800x566.jpg)
Vehicle Range
The widespread use of gasoline and diesel is largely explained by energy density and ease of onboard storage. The energy per unit volume is a key determinate to the distance a vehicle can travel before needing to be refueled. LNG has lower energy density per unit volume than diesel and therefore has a lower range than diesel, but higher range than CNG. A comparison of fuel volume and range for diesel, LNG and CNG is given in Figure 18.
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The density of LNG, and therefore the amount of energy in the equivalent volume of fuel, is related to the temperature and pressure in the tank. LNG at lower temperature and pressure will provide an increased range for the vehicle and a longer hold time in the fuel tank34 . For example, a truck fueled with LNG at 50 pounds per square inch gauge (psig) has range up to 740 miles and a hold time up to 10 days, compared to a super warm tank of LNG at 225 psig, which has a range up to 620 miles and one day hold time, Figure 19.
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LNG Quality
Variations in LNG quality could cause inefficiencies and equipment performance issues for the end user. Although a number of guidelines exist for fuel composition for natural gas engines, there are few standards in existence. The principal constituent of natural gas is methane (CH4) with smaller quantities of other components including heavier HC, hydrogen sulfide (H2S) and inerts (e.g. CO2 and nitrogen (N)). The natural gas is treated to remove impurities and gas liquids, then liquefied through a refrigeration process to approximately -260˚F (-162˚C) to yield LNG. Typically LNG consists of 83% to 97% CH4 with small amounts of ethane (C2H6), propane (C3H8), butanes (C4H10) and trace amounts of nitrogen gas (N2). The design of the liquefaction plant, usually based on the specification required by the end user, will determine the composition and quality of LNG produced. LNG quality therefore varies depending on the source of the LNG (i.e. which liquefaction plant it is produced by), as well as transportation time, during which the composition can change slightly due to the evaporation or boil off of lighter components. LNG quality is typically described using a measure of energy content (e.g. gross calorific value), the combustion characteristics of the LNG (e.g. Wobbe Number, Soot Index, or Incomplete Combustion Factor) and the impurities contained in the LNG (e.g. % sulphur, CO2, N2). Gross heating value is a key measure of LNG quality since LNG is sold on an energy basis. The range of gross heating value (and other key quality parameters) for a variety of different sources of LNG is given in Figure 20, showing a range of 39.92 MJ/m3 to 46.24MJ/m3 . Further information is given in Appendix 9.h, LNG Quality and Methane Number
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LNG as truck fuel
Our LNG as truck fuel is one of the leading supplies that you shouldn’t have missed. Gms Interneer help you offer LNG Special Vehicles – LNG Forklift Truck, LNG Special Vehicles – LNG mining dump truck, LNG Heavy Vehicle Tractor – Triple Cylinder Type, LNG Heavy Vehicle Tractor – Double Cylinder Type to deliver across the world.
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Industrial gas LNG
INDUSTRIAL GAS by CIMC ENRIC Holdings Ltd to become the world’s leading major equipment manufacturer and service providers of engineering and system solutions for the energy, chemical and beverage industries such as Cryogenic Thermal-insulating Cylinder
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Water Treatment
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Processing and separation technologies such as high potential water treatment excellent technologies such as Sulfate Removal System – Effective treatment of seawater for injection , Effective SEA-SCREEN Coarse Strainer, Polymem UF Seawater Ultrafiltration System ,UNICEL Vertical IGF – Induced-Gas Flotation Unit,Reverse Osmosis Systems for removing dissolved salts. from seawater, CYCLOTECH Cyclonic Separation Technologies,EPCON Dual Compact Flotation Unit (CFU), which is suitable for oil and gas industry.
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LNG Station
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LNG Station
- LNG pressure regulator unit
- LNG Ambient Air Vaporizer (AAV)
- LNG storage tank for Permanent LNG station
- Vertical Cryogenic Tank
- Horizontal Cryogenic Tank
- LNG Regasification Station
- LNG Regasification Station
- Microbulk LNG Tank
- Cryogenic Liquid Storage Tank Microbulk
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Magnetrol
Magnetrol , we believe in the future of advanced process and technologies. With our sophisticated experts, We design our products with the highest standards of excellence such as External cage type level switches,Magnetrol External Chamber,External Cage Liquid Level Switch for Power Industry,Eclipse Model 706 Wave Radar Level Transmitter,Displacer Type Liquid Level Switches,Digital E3 Modulevel Liquid. Level Displacer Transmitter .
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Smith Gasket
Our dedicated and sophisticated Smith Gasket team continues to deliver innovative concepts and premium products worldwide. Smith International Gulf Services supplies a wide range of oilfield products and services,including industrial gaskets advanced cutting service and high-tech testing facilities such as RING TYPE JOINTS TYPE R, RING TYPE JOINTS TYPE RX,RING TYPE JOINTS TYPE BX , SPIRAL WOUND GASKETS, etc.
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Other parts supply
Theses are other part supplies from many leading manufacturers brands which are related to the fuel industry such as HONEYWELL, SMITH GASKET ,ORION, MAGNETROL
- HONEYWELL
- SMITH GASKET
- ORION
- MAGNETROL
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What is Cryogenic Tanks
Cryogenic Tanks
Metal processing, medical technology, electronics, water treatment, energy generation, and food processing are among businesses that use liquefied gases. A growing number of these industrial gases are now given to customers in liquid form at cryogenic temperatures, enabling them to be stored on-site for future use.
Cryogenic tanks are used to safeguard cryogenic liquids. Cryogenic liquids are typically liquefied gases with temperatures as low as -150 °C. Byproducts include oxygen, argon, nitrogen, hydrogen, and helium. Cryogenic tanks may also be used to store gases at higher temperatures, such as LNG, carbon dioxide, and nitrous oxide. These are components of gas supply systems used in a number of sectors including metal processing, medical technology, electronics, water treatment, energy generation, and food processing. Low temperature chilling applications such as engineering shrink fitting, food freezing, and bio-sample storage also make use of cryogenic liquids.
Cryogenic tanks are thermally insulated, generally with a vacuum jacket, and are designed and manufactured to rigorous specifications in compliance with international design norms. They may be fixed, movable, or transportable.
Static cryogenic tanks are designed for permanent usage; however, transportable small tanks on wheels for use in workshops and laboratories are provided. Because static cryogenic tanks are often classified as pressure vessels, new tanks and associated systems will be constructed and installed in accordance with the Pressure Equipment (Safety) Regulations. For applications requiring direct access to the liquid, non-pressurized open neck vessels (Dewar flasks) are also available. The tanks are available in a range of sizes, pressures, and flow rates to meet the diverse demands of the customers. Tanks used to transport cryogenic liquids must comply with the Regulations on the Carriage of Dangerous Goods and the Use of Transportable Pressure Equipment.
Cryogenic tank use, operation, and maintenance
All relevant rules, such as the Pressure Systems Safety Regulations for static tanks and the Carriage of Dangerous Goods and Use of Transportable Pressure Equipment Regulations for transportable tanks, must be followed while operating and maintaining cryogenic tanks. Cryogenic tanks must be maintained and handled by trained personnel.
The Regulations require cryogenic tanks to be inspected on a regular basis, as well as routinely maintained and subjected to formal examinations on a periodic basis for static tanks. To ensure that the tank is in safe operating condition between official examination times, an inspection and maintenance program should be created. This will include a Written Scheme of Examination created by a competent person(s), as well as periodic formal examinations conducted in accordance with the scheme. Refer to BCGA CP 39.
Transportable tanks must be inspected and tested on a regular basis, which may only be done by an Inspection Body recognized by the National Competent Authority, Department for Transport, in the United Kingdom (DfT). The Vehicle Certification Agency (VCA) website provides information on Examination Bodies that have been authorized to execute various activities relating to tank and/or pressure equipment inspection.
All inspections, examinations, and tests are documented, and these documents must be kept for the duration of the tank’s life.
Users and owners of cryogenic tanks have legal requirements and a duty of care to ensure that their equipment is properly maintained and operated. BCGA L12 provides best practices guidance and help. According to BCGA CP 48, a gas supplier will only fill a tank if it is safe to do so. The user must undertake routine safety inspections. According to BCGA L11, daily inspections must be undertaken. While in use, a little quantity of frosting and ice may be seen. Small quantities of ice should not cause concern, but the quantity of ice should be monitored on a frequent basis. De-cing should be conducted if ice continues to collect to minimize excessive ice accumulation, according to BCGA L21.
Repair and modification of cryogenic tanks
Any repair or modification to a cryogenic tank must be performed only by a certified repairer in accordance with the design standards to which it was constructed, while taking current laws and legislation into account. Such repairs or adjustments must not threaten the structure’s integrity or the operation of any protective measures. All repairs and adjustments must be documented and kept on file for the life of the tank, according to BCGA CP 39.
Revalidation of cryogenic tanks
Cryogenic tanks must be assessed on a regular basis to ensure their safety for continued use. The revalidation period, which should not exceed 20 years, shall be determined by a Competent Person. Mobile tanks should be hired for a shorter period of time due to the nature of their purpose. Refer to BCGA CP 39. When a tank is revalidated, a report is created that must be kept together with the tank data for the life of the tank.
Cryogenic tank disposal
Because certain cryogenic tanks contain hazardous compounds in their vacuum region, such as perlite, they should only be disposed of by a certified and experienced disposal company. All pressure equipment must be designed to be non-reusable.
Committee
Technical Sub-Committee (TSC) 1 is in charge of committees within BCGA cryogenic tanks. TSC1 information is available to members via the ‘Members’ section.
Publications
BCGA produces a range of publications that give knowledge and help on how to use, store, transport, and handle cryogenic gases appropriately. The ‘Publications’ page contains links to all BCGA publications. The following are particularly noteworthy:
BCGA CP 26 – Bulk liquid carbon dioxide storage on the premises of users.
BCGA CP 27 – Transportable vacuum-insulated containers with a capacity of no more than 1000 litres.
BCGA CP 36 – Cryogenic liquid storage on the premises of the user.
BCGA CP 39 – Pressure equipment in-service requirements (gases storage and gas distribution systems).
BCGA CP 46 – Cryogenic flammable fluid storage.
BCGA CP 48 – The safe filling of tanks owned and/or managed by third parties
BCGA GN 19 – Cryogenic sample storage systems (Biostores).
BCGA TIS 23 – BCGA policy on static cryogenic liquid storage tank interior inspection and proof pressure testing.
BCGA L 11 – Cryogenic tank safety inspections
BCGA L 12 – Your Liquid Gas Storage Tank Responsibilities
BCGA L 21 – Cryogenic Installation Managing the accumulation of ice
In the refrigeration process, three main components that we encounter unavoidably are: Condenser, Chiller and Chiller. LGN system and Cryogenic system are also, comprised of this 3 main equipment.
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What is LNG Cylinder
LNG Cylinder
Natural gas is mostly composed of methane (often at least 90%), although it may also include ethane, propane, and heavier hydrocarbons. The “pipeline” of natural gas may also include trace quantities of nitrogen, oxygen, carbon dioxide, sulfur compounds, and water. During the pre-treatment process, oxygen, carbon dioxide, sulfur compounds, and water are all removed.
The liquefaction process compresses, cools, condenses, and reduces the pressure and temperature at which methane, the principal component of natural gas, liquefies. The whole process may be adjusted to produce the purest form of LNG.
Storage and regasification of LNG Cylinder
By storing LNG and providing natural gas to final users, LNG receiving terminals contribute to the LNG value chain. A pipeline, LNG storage tanks, compressors, vaporizers, pumps, and other components are often included. The LNG from the LNG carrier ship is transferred to the storage tank through the unloading pipeline. The stored LNG is transported to the vaporizer process by a pump in the storage tank. The vaporization process is used to provide natural gas to the end user.
Recirculation, depressurization, and unloading are all steps in the LNG unloading process. To prevent pipeline heat prior to LNG unloading, the unloading pipeline must be kept cryogenic. A little amount of LNG from the storage tank is continually cycled through the pipeline during the recirculation stage to keep it cool. The pipeline pressure is decreased to the amount necessary to carry LNG from the carrier to the storage tank during the depressurization process. Following the unloading stage, the process advances to the first phase of recirculation.
The vapor from the LNG constantly evaporates due to the absorbed heat in the storage tank and the cryogenic pipelines during the unloading and storage of LNG. This vapor is referred to as boil-off gas (BOG). Because of the 600-fold increase in volume, it may cause physical damage in LNG facilities. When the BOG is over-treated, more energy is used. As a consequence, effective BOG management is required for energy savings. For LNG receiving facilities, re-condensation and direct compression are popular BOG handling processes. Using a BOG compressor, BOG from the storage tank is compressed to roughly 10 bars and blended with enough send-out LNG to generate a liquid mixture, which is then pumped into the re-condenser. The liquid combination is compressed to supply pressure and evaporated by saltwater in a high-pressure (HP) pump. The BOG will not be condensed in the re-condenser if the LNG rate indicated in the requests is insufficient to condense all of it. The HP compressor compresses the residual BOG in the re-condenser to pipeline pressure and instantly delivers it to the pipeline, where it is mixed with the natural gas (Park et al., 2010). Because the HP compressor uses a substantial amount of energy, it is desirable to decrease the HP compressor’s operation.
Refrigeration
No amount of insulation, no matter how efficient, can keep the temperature of LNG cold on its own. LNG is stored as a “boiling cryogen,” which implies that at its boiling point at the pressure at which it is stored, it is a very cold liquid. The temperature of stored LNG is comparable to that of boiling water, but 470°F [243°C] lower. The temperature of boiling water (212°F [100°C]) does not change with increasing heat because it is cooled by evaporation (steam generation). Similarly, if kept at constant pressure, LNG will keep its temperature close to constant. This is referred to as “auto refrigeration.” As long as the steam (LNG vapor boil off) is allowed to depart the tea kettle, the temperature will remain constant (tank).
If the vapor is not removed, the pressure and temperature inside the vessel will rise. Even at 100 psig [6.7 barg], the temperature of the LNG will be about -200°F [-129°C].
Cylinder of LNG Vehicle Fuel
The vehicle cylinder is a vacuum super insulated cryogenic container that allows liquid natural gas to be stored at low temperatures for lengthy periods of time with very little usage.
- Make safety your first concern. Only manufacture LNG cylinders that pass the inspection items outlined in the Codes and Standards.
- Extremely long service life Using acquired expertise and know-how, manufacture cryogenic liquefied gas cylinders for industrial applications.
- Superior thermal insulation 90 percent insulation technology that does not bend even after being completely charged for 5 days
- A straightforward repair structures
- Plan for easy component replacement in the case of a problem.
- Customized production based on customer specifications We have superior cylinder design and manufacturing methods that enable us to respond swiftly to demands regardless of vehicle type or volume.
As we can see, LNG storage system is working on the very low range of temperature, or on the cryogenic process. It is important and mandatory that to operate in the low region temperature, the materials and process have to withstand the cryogenic effect. This causes the cryogenic tanks to be considered as one of the main component and important equipment for LNG Storage System as well.
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What is LNG STORAGE SYSTEMS
LNG STORAGE SYSTEMS
Natural gas provides clean, reliable, and cost-effective energy to people all around the world. Natural gas is a cryogen, which implies that at extremely low temperatures it is a liquid. Natural gas may be transported as a liquid from locations with abundant supply to areas with high demand in an efficient and safe manner.
LNG storage tank systems keep the gas in a liquid state for storage or transmission. These tank systems are meticulously designed and well-built. In LNG storage systems, auto-refrigeration is employed to maintain constant pressure and temperature in the tank. This method is, in reality, quite old. West Virginia built the first natural gas liquefaction plant in 1917. Many advancements have been made since then to increase natural gas storage, but the systems continue to function in the same way. Here’s what we need to know before designing and constructing an LNG storage system.
API Standards and Codes
In the 1960s, the American Petroleum Institute (API) established rules for the design, construction, and material selection of storage tank systems. These standards contribute to the overall safety and quality of the industry. API codes are also continually updated to reflect industry innovations and best practices.
Types of LNG Storage Tanks
Liquefied gas storage tanks are classed based on their kind and size using a range of standards and guidelines that differ in terms of when they were published and the quantity of information they give. The wording used by the two German standards, DIN EN 1473 and DIN EN 14620, is even diametrically opposite. This section will utilize either the vocabulary from the British equivalent, BS EN 1473, or the nomenclature from API 625. API 625’s British counterpart is BS EN 1473. From a practical sense, the phrase “containment tank system,” as used in API 625, seems to be the most appropriate, since the multiple, yet coordinated, components interact to create a cohesive system. Containment tank systems are categorized as single, double, or complete according to the standards EEMUA, BS 7777, EN 1473, EN 14620-1, NFPA 59A, and API 625. The membrane tank is an extra tank type that is detailed in further detail in the European standards EN 1473 and EN 14620.
Until the 1970s, the only kind of tank built was the single-wall tank. The hazard scenarios that resulted from abnormal actions such as inner tank failure, fire, blast pressure wave, and impact inspired the subsequent further development of the various types of tanks or tank systems, as well as the associated requirements placed on the materials and construction details. Because of the threats that a tank failure brings to the surrounding areas, it is essential to choose the proper kind of tank system.
The repercussions of a failure of the inner container on the tank as a whole and its surroundings for three commonly used tank systems will be shown utilizing the failure of the inner container. The evolution of these three tank systems will also be studied.
System with a single containment tank
A container that is both liquid and vapor tight is referred to as a single containment tank system. It may be built as a single-wall, liquid- and vapor-tight structure, or as a combination of inner and outside containers. In the latter case, the inner container is open at the top and liquid tight. When an outside container is used, it is largely to enclose the insulation and protect it from moisture, as well as to accommodate the gas vapor overpressure. It is not designed or intended to store LNG that has spilled from the tank. If there is just one containment tank, it must be surrounded by some form of safety barrier, usually an earth embankment, to prevent the liquid from escaping uncontrolled and causing damage.
The inside container of an EN 14620 container must be made of steel, but API 625 permits for the use of prestressed concrete in some situations. If you use an outside container, it is normally made of carbon steel to keep the elements out.
System with two separate containment tanks
Double containment tank systems are made up of a liquid- and vapor-tight primary container that satisfies the criteria for a single containment tank system but is contained within a secondary container that fits the criteria for a double containment tank system (Fig. 4.2). In the event of a leak, it is intended to be open at the top and capable of capturing any liquefied gas that escapes. On the other hand, it is not meant to obstruct gas escape. In order for the primary and secondary containers to operate effectively, no more than 6 m must be left between them. According to API 625, both steel and prestressed concrete are permissible materials for both containers.
System with a Complete Containment Tank
A complete containment tank system is made up of primary and secondary storage containers that work together to provide a comprehensive and integrated storage system. The primary container is a cylindrical steel tank with a single self-supporting and self-contained shell. Alternatively, it might be open at the top, rendering it incapable of holding any vapors, or it could be built with a dome roof, preventing vapor from escaping in such a case.
The secondary container must be a self-supporting tank made of steel or concrete with a dome roof in order to qualify. If the main container is open at the top, the secondary container must function as the primary vapor containment for the tank during normal operation. In the case of a leak from the primary container, the secondary container must be capable of storing the liquefied gas and remaining liquid-tight while also functioning as the primary vapor containment structure. It is permissible to vent in a regulated way using the pressure release mechanism. API 625 states that “product losses due to permeability of the concrete are permitted” when the outer container is made of concrete. According to API 625, both steel and prestressed concrete are permissible materials for both containers. The existence of vapor-tightness is required for normal operation. Figure 4.3 displays a number of various design options, one of which incorporates a prestressed concrete inner tank.
The standards EN 14620-3 (Annex B) and ACI 376 (Appendix A) specify and illustrate sliding, pinned, and fixed connections between a wall and a foundation slab. Sliding or pinned joints are employed in certain circumstances, however this is only possible in small tanks operating at less severe low temperatures and consequently with less overpressure. Due to the nature of the material, the monolithic wall/base slab connection is the only practical method for LNG tanks.
In order for the system to continue to work properly in the event of inner container failure, the conventional complete containment tank with a concrete outer container and solid monolithic connection between wall and base slab must have two constructional qualities. In such a circumstance, the wall experiences a temperature difference of roughly 100 K and temperature gradients of up to 200 degrees Celsius. With the tank sizes that are commonly employed, this temperature disparity results in a radial shortening of the tank wall of 4–5 cm, depending on the diameter. If no further safeguards are taken at the wall/base slab junction, a failure of the concrete cross-section will occur. One alternative is to build a transition zone at the base of the wall that is at least 5 meters high in order to reduce the contraction of the concrete wall to a level that is commensurate with the surrounding environment. In practice, this is done by including an insulating layer between the base slab and the wall, which comprises a secondary bottom made of nickel steel (9 percent nickel content). The secondary bottom is higher up the wall than the main bottom. Thermal corner protection refers to this section, which is protected with insulation and steel plates (TCP).
This feature protects the insulation while also aiding it in retaining its thermal function, reducing the influence of temperature on the cross-section of the concrete and smoothing the development of deformation. Despite the fact that experience has shown that the risk of a single containment tank failing (assuming it was built in accordance with regulations) is extremely low, such risks can be reduced even further by introducing even stricter requirements regarding material selection, design, construction, inspection, and testing. However, the implications of a tank collapse are so severe for particular hydrocarbon chemicals that an even more complex tank design is necessary to avoid them. The tank system should be chosen with the location, operating conditions, and environmental standards in mind, among other things.
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What is Air Cooled Condenser
Air Cooled Condenser
Due to rising environmental laws and public pressure, many facilities are being forced to convert existing power plants to closed-circuit cooling water systems or even dry cooling alternatives, rather than continuing to utilize once-through river or ocean cooling water. In arid locations, there simply isn’t enough water to fulfill the needs of both power plants and people.
Dry cooling may also be chosen early in a project by the intelligent developer since it widens plant siting options and may significantly speed up construction permit clearing because water use constraints are avoided. Even a six-month delay in a project’s timeframe may drastically affect its economics and easily cover the greater capital cost of dry cooling systems.
Basic Concepts of Air Cooled Condenser
- ACC is a direct dry cooling system that uses vacuum to condense steam inside air-cooled finned tubes.
- Ducting (for steam transmission), a finned tube heat exchanger, axial fans, motors, gear boxes, pipes, and tanks are the primary components of an ACC (for condensate collection).
- To condense the steam, ambient air passes across a finned tube heat exchanger with a forced draft axial fan.
The ACC’s major component is the finned tube heat exchanger, which comes in a variety of configurations:
- SRC (Single Row Condenser)
- MRC (Multi Row Condenser) (MRC)
The basics of air cooled condenser design
In contrast to once-through water-cooled facilities, direct dry cooling condenses turbine exhaust steam inside finned tubes that are externally cooled by ambient air rather than sea or river water. There are two methods to circulate ambient air for condensate cooling: employ fans to move the air or take use of nature’s draft.
The well-known hyperbolic tower, which can reach heights of more than 300 feet and is outfitted with a series of heat exchangers, is used in the natural draft system. The second, more well-known design alternative is the air-cooled condenser, which uses motor-driven fans rather than hot air’s inherent buoyancy. Natural draft is a specific use for small places due to the vast size of hyperbolic structures. As a consequence, an air cooled condenser with mechanical draw is used in about 90% of the world’s dry-cooled power plants.
The steam from the turbine exhaust enters a steam distribution manifold located on top of the ACC structure. The steam is subsequently diffused by fin tube heat exchangers arranged in an A-shape in a “roof structure.” The cooling effect of ambient air drawn over the external finned surface of the tubes by the fans causes steam to condense inside the tubes. The fans are positioned at the base of the A-shape structure. Condensate drains from the fin tube heat exchangers into condensate manifolds and then to a condensate tank before being routed to the boiler or the typical feed heating plant.
An ACC operates under vacuum in the same manner as a conventional surface condenser does. Air and other non-condensable gases enter the steam through a number of sources, including system border leaks and the steam turbine. Non-condensable gases are evacuated in the “secondary” portion of the ACC, which is attached to vacuum pumps or air ejectors that exhaust the non-condensable gases to the atmosphere.
The fundamental difference between ACC designs from different manufacturers is the heat exchanger and its finned tubes. Heat exchangers are classified into two types: single-row and multi-row. There are several arguments for and against the advantages of each idea. In very cold conditions, the single-row architecture is obviously preferable. Furthermore, the market provides three tube shapes: round, oval, and flat. The most sophisticated tubes are spherical and flat, and they perform well in practically all conditions.
Suppliers also vary in terms of fin shape. Certain fin shapes are less prone to fouling and mechanically more resilient under transitory conditions. Fins of the best quality have a strong connection to the bare tube, resulting in a useful life expectancy comparable to that of power plants.
The last critical design element is the material utilized for the finned tubes. Aluminum fins brazed on flat bare aluminum tubes wrapped in aluminum, or oval galvanized finned tube bundles, are usually considered as the two most reliable power plant technologies.
If ACC is selected, a plant site in China, as well as other locations across the world, is not required to be near a water source. Transmission lines and either gas distribution lines (for combined-cycle facilities) or rail lines might be optimized instead (for coal-fired plants). China’s solid fuel plants are often situated near coal mines, explaining the country’s present interest in air cooling. Finally, if a lake, river, or coastal plant site is not required, property costs may be reduced.
Air Cooled Condenser Market
During the 1960s and 1990s, Europe had a very small market for large or medium-sized power plants. It was instead reliant on enormous coal-fired power plants and nuclear reactors. In contrast, due to water constraint, dry-cooling designs have risen in popularity in the Middle East, China, South Africa, and the United States (at coal mine locations, in desert environs, or for other similar reasons). The worldwide market for dry cooling began to flourish after 1990, and it has more than quadrupled in the previous 13 years.
Given China’s large electrical requirements, the market for dry-cooling equipment is expected to remain active in the near future. Reasonable growth is also expected in Europe, as some European Union member countries renew their interest in managing future water supplies. The Middle East (Emirates area) and India will surely become two tremendously important markets in the near future. The market in the United States has been gradually growing since the middle of 2005
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What is Vaporizer
Vaporizer
Heat is used by vaporizers to evaporate a working fluid. They are often compared to industrial boilers, but do not generate significant pressures. In low pressure vaporizers, the vaporized stream is typically used as the heat exchange fluid. They are also capable of evaporating liquid fuels and cryogenic liquids.
Vaporizer Types
The primary distinction between vaporizers is their function. Vaporizers are devices that either produce vapor or transfer heat. Vaporizers, which generate vapor from a liquid stream, are frequently used. Propane vaporizers, for example, evaporate liquid propane (lp) to provide propane gas to equipment. In frigid areas where natural vaporization from storage is insufficient, or in systems with high vapor needs, this is essential.
Vaporizers may also be used with other fuels such as gasoline and kerosene, most notably for engine fuel injection. They may also superheat or evaporate low-temperature fluids such as liquefied natural gas or liquid nitrogen. They may also be used to heat liquid feeds in order to generate steam or other hot gases.
Vaporizers may also be used as heat transfer devices, thanks to the use of vaporized heat transfer fluids and refrigerants. Using vapors to transport liquids or solids over surfaces decreases pressure and increases temperature uniformity. These devices make use of a shell and tube heat exchanger, with the vaporized fluid contained inside or outside the tubes. Heat exchange vaporizers may use single-component or multi-component heat transfer fluids.
Heat Source
The heating source of the evaporated fluid distinguishes vaporizers.
- Ambient vaporizers evaporate cryogenic and other cold liquids using ambient heat.
- Pre-heated water or another hot liquid is used to evaporate in hot water vaporizers. This helps temperature control.
- Radiant heat vaporizers heat using radiant energy rather than convection or conduction.
- Preheated steam or a comparable hot gas is used to vaporize in steam vaporizers. This enhances temperature control and heat transfer to the boiling liquid.
Performance Specs
The performance of a vaporizer is determined by a few key parameters. The capacity of the device is measured in gallons per hour (gph), kilograms per hour (kg/h), or similar mass or volume per time units. Rather than heat transfer vaporizers, this standard is used to assess vaporizers. The maximum working temperature of the vaporizer (or the maximum heat transfer fluid temperature of the system)
Power requirements for vaporizers that use electric heat or other electrical equipment. kW is the most used unit of measurement for power (kW). The maximum pressure at a particular temperature is referred to as the operating pressure (typically the maximum temperature). Pressure is often given in pounds per square inch (psi) (psi).
Features & Extras
In certain circumstances, the features or supplemental equipment of a vaporizer are crucial. Condensate pumps are used to push excess fluid or condensate back into the vaporizer system. Because of gravity return, the vaporizer does not need a pump to return the condensed fluid.
Hartford loops are used in most vaporizer systems to prevent liquid from flowing in the wrong direction due to gravity. They keep an eye on and adjust the liquid levels in the vaporizer tank. The power (voltage and/or current) of the vaporizer is regulated by power controls. Parts may be replaced without first emptying the system, saving time and money on maintenance and repairs.
Standards
Standards for industrial vaporizers have been set by the American Society of Mechanical Engineers (ASME). These specifications ensure that the equipment is both safe and efficient. For further assurance, industrial vaporizers may be certified with the National Board of Boiler and Pressure Vessel Inspectors.
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What is Steel Pipe
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Steel Pipe
Steel pipes are cylindrical steel tubes that are utilized in a number of industrial and infrastructural applications. They are the most often utilized product in the steel industry. Pipe is mostly used to transport liquids or gases underground, such as oil, gas, and water. Despite this, pipes of varied diameters are widely used in industry and construction. A common example of home manufacturing is the thin steel tubing that powers the cooling mechanism in refrigerators. In the building industry, pipes are utilized for heating and plumbing. Handrails, bike racks, and pipe bollards may all be made out of steel pipe of different sizes.
Steel Pipe Manufacturing Process
This ubiquitous building material is created in two unique techniques, beginning with the melting of raw components and ending with the molding or welding of completed products:
1. The first stage is to transform raw steel into a more useable form.
Both methods must start with the manufacture of high-quality steel. Raw steel is produced at foundries by melting raw materials in a furnace. Components may be added to the molten metal and impurities removed to exactly balance the composition. After that, the molten steel is either poured into molds to make ingots or transferred to a continuous casting process to produce slabs, billets, and blooms. Pipe is made from slabs or billets of steel.
2. Steel slabs and steel skelp in pipe manufacturing
Slabs are heated to 2,200 degrees Fahrenheit to make steel skelp. The heat causes a scale to build on the surface, which must be cleaned using a scale breaker and high-pressure cleaning. After the steel slab has been cleaned, it is hot rolled into thin, narrow steel strips known as skelp. Skelp is pickled (surface cleaned) using sulfuric acid before being washed and rolled into massive spools as a raw material for pipe manufacturing. The width of the skelp determines the diameter of the pipe that may be manufactured.
Steps to completion
Pipes may be straightened as a last manufacturing process before being joined. Threaded couplings are often used in small bore pipe, while welded-on flanges are used in larger bore piping. For quality control purposes, measuring equipment verifies the finished pipe’s measurements and stamps the information on the pipe’s side.
Control of quality
Using x-ray equipment to check the pipe for faults, especially along the weld, is one of the quality controls processes. Another way is to pressure test the pipe by filling it with water and then holding it under pressure for a certain amount of time to identify any defects that might lead to catastrophic collapse before putting it into service.
Steel pipe Utilization
Pipes are used in many different purposes, including as building, transportation, and industrial. They are measured by their exterior diameter, with the interior diameter varying according to wall thickness. Certain applications need thicker walls than others, depending on the stresses that the pipe must handle.
Utilization in structures
In architecture and construction, structural applications are common. Steel tubes are a phrase that is often used to refer to the building material in a variety of industries.
Pipes used in construction
Steel tubes are used to strengthen foundations using a procedure known as piling. In these cases, the tube is driven deep into the earth before the foundation is laid. It provides stability for a towering building, or a structure built on unsteady ground. Fundamentally, pile foundations are of two types:
- End bearing piles have a bottom end that is supported by a thick layer of soil or rock. The load of the building is communicated to the strong layer through the pile.
- Friction piles transfer the weight of the building to the soil by friction across the whole height of the pile. The pile’s whole surface area contributes to force transmission to the earth.
Poles for scaffolding
Scaffolding poles are constructed by connecting steel tubes in a cage to provide access to places above ground level for construction workers.
Industrial application
Guard rails: constructed of steel tubing, they are used to protect cyclists and pedestrians. Guard rails, which are also made of steel tubes, are an appealing safety feature for stairs and balconies.
Bollards: Bollards are used to safeguard people, buildings, and infrastructure by separating them from motor traffic.
Bike racks: Steel tubes are bent to form a huge range of commercial bike racks. Steel’s strong material properties make it impregnable to intruders.
Transportation use
Steel pipes are the most often utilized material for product transportation since they are well-suited for long-term installations. It can be buried underground because to its hardness and resistance to disintegration. Low pressure applications do not need the use of robust pipes since they are not exposed to significant stresses. A small wall thickness allows for a more cost-effective production procedure. Specifications for more specific applications, such as pipes used in the oil and gas industry, are more stringent. Because of the hazardous nature of the chemical being transported and the possibility of increased pressure on the line, a high degree of strength and hence a thicker wall are required. This frequently results in a higher price. Quality control is critical for these applications.
Steel pipes, which are used to transport items such as oil, gas, and water, are perfect for long-term installations.
Procedure for specifying steel pipe
There may be some confusion about how these materials are defined and what they mean in terms of the actual qualities of the pipe. The three most often referenced organizations in North America for pipe standards are the American Society for Testing and Materials (ASTM), the American Society of Mechanical Engineers (ASME), and the American Petroleum Institute (API). Specifications are divided into three categories:
1. Pipe nominal diameter
“Nominal Pipe Size,” or NPS, is the acronym for pipe size. The origins of NPS values for smaller diameter pipes (NPS 12) differ from those for bigger diameter pipes. However, all pipes with the same NPS number have the same outside or outside diameter (OD). Internal diameters vary depending on the thickness of the metal’s wall. This is done to guarantee that the same structural supports may be used for all pipes with the same NPS value, regardless of wall thickness.
2. Schedules
Steel pipe schedules are a means of specifying the wall thickness of a pipe. This is an important feature since it has a direct link with the pipe’s strength and suitability for certain applications. Given the design pressure and allowable stress, a pipe schedule is a dimensionless number that is calculated using the wall thickness design formula. Here are some examples of schedule numbers: The most common schedules are 5, 5S, 10, 20, 30, 40, 50, 60, 80, 100, 120, 140, 160, STD, XS, and XXS. The schedule number denotes the thickness of the pipe’s wall. The inner diameter of a pipe is defined by the schedule number, just as the OD is determined by the NPS number.
3. The pipe’s weight
The NPS (outside diameter) and the schedule may be used to calculate the weight of a pipe (wall thickness). The constant is calculated using steel’s theoretical weight of 40.8 pounds per square foot per inch of thickness: W = t (OD – t) multiplied by 10.69
Where:
- W represents for weight (in pounds per foot).
- OD stands for outer diameter; and
- t stands for thickness.
4. Certification
A Material Test Report, also known as a Mill Test Report, is provided by manufacturers to confirm that the product meets the stipulated chemical analysis and mechanical qualities. The MTR will contain all relevant product information and will accompany it throughout its life.
Some of the common parameters that an MTR may record are as follows:
- The material’s chemical makeup, including the quantity of carbon, alloys, and sulfur.
- Material dimensions, weight, identity, and grade
- The heat number of the material, which corresponds to the processing batch; and
- Tensile strength, yield strength, and elongation are mechanical qualities. The most often referenced steel bollard standards are ASTM A53 and ASTM A500.
For Oil & Gas and Petroleum Business, the types or the standard for the steel or metal pipes that has been used widely is API (American Petroleum Institute) standard. We call the pipes manufactured according to API standard as “API Pipes”
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What is Absorption Chiller
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In contrast to typical chillers, absorption chillers use waste heat from other processes or equipment to drive a thermodynamic process that allows water to be chilled and distributed for HVAC needs. In place of conventional refrigerants, water is often coupled with either ammonia or lithium bromide, with lithium bromide being the more preferred option because to its non-toxicity.
Important factors
Because absorption chillers do not require electric compressors, they may provide significant cooling capacity while contributing to peak energy consumption. The most crucial element to consider when assessing the use of such a chiller is that they do need a significant and consistent source of waste heat to function. Although industrial manufacturing facilities are the most obvious candidates, other places like as university campuses, larger hospital complexes, or large hotels may also benefit considerably from the addition of an absorption chiller.
The advantages of using absorption chillers
The principal refrigerants used in absorption chillers have no negative effects on global warming or ozone depletion. An absorption chiller might assist the business in saving money on electricity, hot water, heating, and cooling. The lack of compressors in the machine decreases noise and vibration in the building, resulting in a tranquil environment with high reliability.
An absorption chiller is nearly entirely powered by heat that would otherwise be squandered. It does not need energy to generate chilled water or heat. A considerably larger capacity will not be required in an emergency backup power system.
The Science of Absorption Chilled Water
A condenser, generator, evaporator, absorber, and heat exchanger are all part of an absorption chiller. Initially, the absorber contains the refrigerant or lithium bromide water. It will be driven into the generator tank on the top of the chiller through the heat exchanger. The chiller’s generator will use solar heat or waste steam from other systems. Lithium bromide and water are separated by heat. Water evaporates slowly and rises to the condenser, while lithium bromide sinks.
A conduit will carry the lithium bromide back to the absorber. The vapor will next pass via a cooling tower. The air pressure in the cooling tower pipe is lower than in the condenser. When the air pressure drops, water condenses. The cold water is then evaporated and re-mixed with lithium bromide
An absorption chiller, in a nutshell, cools water by quickly changing pressure. As the water in the generator warms up, the air pressure rises. Water vaporizes when it loses heat. The vapor is then sent to the evaporator to cool. The vapor swiftly cools and condenses to become cold water. Heat is absorbed by vapor, which then condenses to form water.
When water evaporates, it absorbs heat. In a low-pressure environment, the vapor cools and returns to water. The water in the absorber reacts with the lithium bromide and returns to the heat exchanger, carrying with it undesired heat.
With low energy input, an absorption chiller generates cooled water. Throughout the heating and cooling cycles, it will continue to remove heat from the structure.
Working concept
To describe the technique, let’s start with the generator. A condenser, absorber, and evaporator are all part of this chiller. This process produces a liquid refrigerant solution that can be pushed to greater pressures. This pumping method is used to replace mechanical compression that is powered by electricity.
Generator
Pour in the heated, diluted solution. On a heat exchanger that carries hot water or another source of heat. When the solution boils, it produces refrigerant vapor as well as a hot concentrated solution.
Condenser
Once in the condenser, the vapor is converted back into a liquid via a colder heat exchanger. The liquid refrigerant can reach the evaporator thanks to a temperature and pressure reduction expansion valve.
Evaporator
Low-pressure refrigerant is introduced as a mixture of liquid and vapor. This area is designed to help you unwind. The evaporator chills water for cooling in commercial buildings.
Absorber
The refrigerant enters the absorber after passing through the evaporator. The absorber absorbs the refrigerant vapor and dilutes it. The heat generated is dissipated by the cooling water.
Absorption chillers Utilization
While absorption chillers outperform conventional cooling systems in the areas we’ve just addressed, proper and regular maintenance is essential for best performance. This is the only way to ensure that the equipment will endure the whole 25 years. A chiller will run perfectly if maintenance staff focus on the following areas: controls, mechanical components, and heat transfer components.
Here are a few examples of issues that need to be addressed:
- Inspect pump shaft seals for wear. • Check for refrigerant leaks. The loss rate should not exceed 1%.
- Heat transfer surfaces must be clean and sludge and scale free.
- Heat exchanger tubes should be free of cracking, pitting, and corrosion.
- Pump bearings may need to be repaired or cleaned.
Absorption Chiller Selection
Even if you use all of the recommended maintenance measures, the equipment will deteriorate, and your maintenance costs will climb. That might be the time to upgrade to more modern, durable, and efficient equipment. If the system is working at part load for a lengthy period of time, a chiller with high part load efficiency may be all that is needed. It is also vital to size the chiller correctly. A chiller that is too big for a certain application will almost definitely operate inefficiently. If exposed to such stresses over an extended length of time, it may develop serious problems. A detailed evaluation of operational requirements, facility type, and timetable should be used to establish the chiller upgrade/selection procedure.
Advantages of absorption chillers
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Advantages of absorption chillers (Source: Shuangliang)
It was briefly discussed at the opening of this article. The following are scenarios when absorption chillers would be favored, according to the concept of absorption chiller functioning and demands.
- Expensive electricity and inexpensive gasoline
- Check to see whether the change is substantial enough.
- There isn’t enough electricity.
- Waste heat is provided (for example from exhaust flow or hot water from engine jacket).
- A adequate supply of hot water or low-grade waste steam.
It will also fit in situations where a quiet environment is required — an absorption chiller is a silent, wear-free system due to the lack of moving components — and needs no maintenance.
How to Install an Absorption Chiller
It is best to work with a contractor that is familiar with sophisticated systems like absorption chillers. Experts can help you design, install, and finance an absorption chiller system that makes financial sense for your company and has a clear path to delivering a fair return on investment.
Apart from its equipment and units that combine into LNG process or LNG storage system, one of the most important part of the system is the connection between each unit and each section. Of course, in the Oil & Gas business or in the petroleum business we use steel pipe as the main transportation means and as the linkage between modules.
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What is Gasket
Gasket
A gasket is an elastomeric component that seals the gap between two surfaces. They are often fashioned from a variety of materials, including rubber, cork or paper, metal, copper, and foam. Because of its adaptability, this versatile element may be used in a range of applications. Anti-vibration, packing, cleanliness, noise and sound reduction, and, probably most importantly, sealing is among them. Gaskets are used in practically every sector, including food, petrochemicals, medicines, water, and gas. Gasket materials are chosen for their qualities and ability to withstand a wide range of circumstances, such as mining and deep-sea environments, as well as resistance to chemicals, alkaline acids, high temperatures, and pressure.
Gasket Functions
In order for a gasket to function correctly and seal away any leaks, it must be compressed enough to produce a full barrier that will establish a pressure-tight seal and protect the contents inside the seal. Furthermore, gaskets safeguard an application’s moving components by keeping them from rubbing against hard surfaces and producing friction. An elastomeric gasket is a component that forms a seal between two surfaces by preventing the passage of gases and liquids. They’re great for filling gaps and linking two surfaces. A gasket must be composed of a material that is easily deformed and covers any defects since it will cover the space between these two surfaces. Compounds like spiral wrapped gaskets are often produced from a mix of metallic and softer filler material (flexible graphite). Metal gaskets must be pressed at a higher tension most of the time in order to seal correctly. In certain cases, a sealant must be applied directly on the gasket to provide a leak-free seal.
Applications for gaskets
Because they are available in a range of specifications, gaskets are a significant component in many manufacturing processes. The material used for a gasket is chosen for its resistance to chemicals, temperatures (or temperature changes), pressures, acids, gases, and, in certain situations, electromagnetic or electrical forces. Gaskets are often found in vehicles, trains, airplanes, boats, electrical equipment, pumps, and a range of other applications.
Industries that utilize gasket
A gasket material has the ability to withstand some of the most demanding conditions for industrial sealing goods, such as:
• Chemical synthesis
• Production of electricity
• Petrochemical and deep-sea exploration
• Oil and gas
• Mining
• Military
• Aerospace
• Filtration
• Food and Beverage
• Pharmaceutical
• Industries involved in sanitary processing
Gaskets may be manufactured using a variety of methods, depending on the material and application, including:
• Extrusion of rubber
• Cold bond splicing and hot vulcanized splicing
• Compression molding, injection molding, and transfer molding
• Slitting with precision
• Personalized die cutting
• Waterjet chop
Gaskets and seals are utilized in almost every application and industry, including oil and gas, manufacturing and industrial applications, pulp and paper production, and agricultural equipment. Gaskets that have gotten worn or broken may be easily repaired. When equipment is removed and rebuilt, it is usual procedure to change gaskets.
Gasket Varieties
In process pipework, three kinds of gaskets are utilized.
• Non-Metallic
• Metallic
• Composite
Gasket Made of Non-Metallic Materials
The most often used materials for this kind of gasket include graphite, rubber, Teflon, PTFE, and compressed non-asbestos fiber (CNAF). These gaskets are also known as soft gaskets. It might have a whole face or an inside bolt circle.
• Non-metallic gaskets are used with low-pressure class flanges such as the 150 and 300 Class, as well as low-temperature applications. Graphite gaskets, on the other hand, can tolerate temperatures of up to 500 degrees Celsius.
• Rubber and elastomer gaskets are used in utility lines rather than hydrocarbon services; and
• Nonmetallic gaskets are affordable and readily available.
Flat-face (FF) flanges need full-face gaskets. Flat ring gaskets may be used in conjunction with raised face (RF) flanges.
Ring Joint Gasket / Metal Gasket / RTJ Gasket
Soft iron, low carbon steel, stainless steel, monel, and inconel are some of the materials used to make metal gaskets. These gaskets are also known as ring gaskets and RTJ gaskets.
• Metallic gaskets are often used in high-pressure class flanges, typically exceeding 900 Class; however, they may also be used in high-temperature applications.
• High tension bolting is required when utilizing metallic gaskets, which are both durable and costly.
The RTJ Gasket is machined into a groove on both mating flanges’ flange faces. With RTJ flanges, two types of metallic gaskets are used: Octagonal and Oval. The distinction may be noted in their cross-section views.
Semi-Metallic or Composite Gasket
Metal and nonmetal materials are used to make composite gaskets. Several material combinations are possible depending on the service need.
• Spiral wrapped, metal jacketed, and kamprofile gaskets are well-known in the composite gasket category.
• Composite gaskets are less costly than metal gaskets, but they must be treated carefully. Composite gaskets are used on raised face, male-female, and tongue-and-groove flanges. '
Importance of Gasket
A flange joint leak might be disastrous. A leaking flange loses both product and energy. No plant operator wants to have a dangerous or hazardous chemical leak that might harm people or the environment. The gasket may help in the establishment of reliable sealing and the prevention of flange joint leakage. Considerations such as: The kinds of gaskets to be used in a certain fluid service are dictated by factors such as:
Temperature – The gasket material must be able to withstand the whole design temperature range of the fluid being managed.
• Pressure – The gasket material must be able to bear the whole design pressure range of the fluid being managed.
• Corrosion resistance – When in contact with the fluid or exposed to the environment, the gasket material should not degrade.
• Fluid types – If installed in a line that handles more than one kind of fluid, the gasket material should be able to handle a wide range of fluids.
• Robustness – The gasket must be able to withstand any movement induced by temperature and pressure changes.
• Availability – The gasket should be easy to find.
• Price – A cheap and unreliable gasket should not be utilized alongside an expensive gasket.
Gasket Selection
The following considerations must be considered while selecting a gasket:
• The gasket material’s compatibility with the fluid.
• The ability to resist the system’s pressure-temperature.
• The gasket’s service life
Before selecting a gasket selection, it is critical to understand the requirements of the application. Gaskets must maintain a seal against all operating forces for an appropriate length of time. There are eight critical characteristics that every gasket must have in order to accomplish this:
• Impermeability – The gasket must be impermeable to the fluid being sealed.
• Compressibility – To form the first seal, the gasket should compress into the flaws on the flange sealing faces.
• Stress relaxation (creep resistance) – When exposed to load and temperature, the gasket should not exhibit considerable flow (creep). This flow will enable the bolts to relax, reducing surface tension on the gasket and causing leakage.
• Resilience – Although usually stable, flanges do shift somewhat relative to one another as temperature and pressure cycle. Such motions should be compensated for by the gasket.
• Chemical resistance –The gasket should be chemically resistant to the process media being handled. Similarly, the gasket material should not contaminate the process media.
• Temperature resistance –The gasket must be able to withstand the impacts of the process’s highest and lowest temperatures, as well as external ambient temperatures.
• Anti-stick – After usage, the gasket must be readily removed.
• Corrosion resistance — The gasket must not corrode the flange faces.
Materials for Gaskets and Seals
Seals and gaskets may be manufactured from a variety of materials, depending on the purposes for which they are intended. Gaskets and seals are often made from the following materials:
• Buna ‘N’ (Nitrile)
• CSR (Hypalon®)
• EPDM
• Flourosilicone
• Fluoroelastomer (FKM)
• Natural Rubber (polyisoprene)
• Neoprene
• Polyurethane
• Silicone
• Synthetic Polyisoprene
• Thermoplastic Rubber (TPR)
• Viton®
Gasket is the sealing function at connections. What goes along with Gasket at each connection are fastening and tightening tools such as Bolts and Nuts. They are both indispensable in connections and sealing functions as well.
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What is Bolts and Nuts
Fundamentals of Bolts and Nuts
A bolt, unlike a screw, is usually accompanied with a nut and a washer in order to function as a fastener. Tightening the nut pushes the things you’re joining together, pressing the washer against one and yanking the bolt head against the other. When matching a nut and washer to a bolt, material, finish, size, and thread type must all be taken into account.
Materials and finishes for bolts, nuts, and washers
Steel is a common material for nuts and bolts however, if they will be exposed to moisture or pressure-treated wood, both of which may corrode steel fasteners, conventional steel fasteners must be coated with a corrosion-resistant coating. There are several popular do-it-yourself finishes:
- Zinc-plated bolts are resistant to corrosion but should only be used indoors. The finish is often thin, will not endure outside weather, and is not suited for use with pressure-treated wood. Yellow zinc or yellow dichromate forms a coating that protects the zinc plating from corrosion, but it is not suitable for outdoor use or when used with pressure-treated wood.
- Hot-dipped galvanized nuts, bolts, and washers are less prone to corrosion. These fasteners are intended for outdoor use and are suitable for use with pressure-treated wood.
- Powder-coated paint finishes are meant to be used on the interior.
- Black phosphate is a coating that improves paint adhesion.
- Black phosphate is a coating that improves paint adhesion. Product information should include specific uses.
- Stainless steel is very corrosion resistant.
- Stainless steel nuts, bolts, and washers are often used in exterior projects and when dealing with pressure-treated wood.
- Hardened steel bolts are frequently used in automotive assembly due to their increased strength.
Sizes of Bolts, Nuts, and Washers
Bolt, nut, and washer sizes will be provided in metric millimeters (mm) or standard (SAE) inches (in). The diameter of a bolt is normally the outside diameter of the threads. Contrast the exterior diameter of a bolt with the inside diameter of a nut and washer. In SAE nuts and bolts, diameters of 1/4 inch or less are represented by a # and a whole number (a bolt with a primary diameter of 3/16 inch is a #10 bolt). The fewer the number, the smaller the dimension.
The length indicates the distance between the end of the bolt and the underside of the bolt head, commonly known as the bearing surface.
Thread Types for Bolts, Nuts, and Washers
Nuts and bolts are threaded either coarsely or finely.
- Coarse-hreaded nuts and bolts have more space between the threads, so match the threading of a nut to the threading of a bolt. They will be distinguished by a higher thread pitch. Coarse-threaded bolts and nuts may be fastened faster because they are less likely to get stuck or cross-threaded.
- Fine-threaded nuts and bolts with smaller thread pitches have less thread gaps, resulting in a tight, strong grip. A fine-threaded bolt’s nut is less likely to be dislodged by vibrations but installing or removing the nut will take longer.
Types of Bolts
Different bolts have different functions. Here are some of the most popular kinds of bolts used in DIY projects.
Bolts with Hex Heads
A hex bolt’s hexagonal head serves as a surface for grasping or twisting the bolt with a wrench, socket and ratchet, or drill/driver. Some hex bolts have threads that extend the whole length of the shank and are often used in threaded holes. They provide high grip strength because they distribute tension over the whole bolt. The thicker, unthreaded segment of a partially threaded bolt provides strength to the fastening process. Partially threaded hex bolts are also beneficial for operations that need more force to hold the work pieces together. Hex-head bolts are commonly used in construction and automotive applications.
Bolts for Carriage
The domed head of a carriage bolt provides it a smooth, polished appearance. It also adds a layer of safety and security since it does not have a driving surface like a hex-head bolt. Carriage bolts are fastened with washers and hex nuts after being inserted into predrilled holes. The nut is secured to the work piece by a square area under the head, allowing you to attach it with a single wrench, socket, or driver bit. Carriage bolts are used in a wide range of applications, such as decks, furniture, and outdoor playsets.
Bolts for anchoring
Anchor bolts are classified as either those meant for use in concrete foundations or those intended for use in a wall. L-bolts are intended for usage in wet concrete. While the concrete cures, the bolt is kept in place. L-bolts may be used to secure a deck post to a concrete pad. To secure retrofit anchor bolts in existing concrete, an adhesive is employed. When drilling into a wall stud is not possible, toggle bolts provide support for hanging things.
U-Bolts
U-bolts have two threaded shanks with a rounded or flattened appearance. Rounded U-bolts are used to secure pipe or conduit to a surface, while squared U-bolts are used to fasten things to a surface, such as a square post. The U-bolt is held in position against the item being secured by two nuts and a metal plate.
Bolts for the eyes
Eye bolts have a loop or ring end and a threaded end for attaching a chain or rope to a wood, metal, or concrete surface. Eye bolts are designed to be used in pre-drilled holes and come with a matching nut. Screw eyes are similar in appearance but have coarser self-tapping threads and a pointed tip that enables them to be driven into a pilot hole in a woodwork item.
Bolts for hanging
A hanger bolt is a fastener that does not have a head. It has machined threads on one end that accept a nut. The bolt’s coarse, self-tapping threads and a point on the other end allow it to be driven into a predrilled hole in wood or comparable material.
Bolts that split
Split bolts are designed to provide secure electrical connections. They enable the splicing of two wires as well as the connection of cables to terminals. Split bolts made of diverse materials work with a variety of wire types. Make sure your bolt is rated for the kind of wire you’re using.
Bolts for the body
Body bolts are often used in the automotive industry. They are used to attach fenders and other components to a car’s body. They have a hex head, a threaded shank, and a washer.
Bolts for Axles
Axle bolts attach wheels to machines like lawnmowers and wagons. The shank’s threaded end receives a locking nut, while the smooth section near the head allows the wheels to rotate.
Types of Nuts
Nuts work with different types of bolts to secure the fasteners. Although some nuts may be tightened by hand, the majority are designed to be driven using a wrench or socket driver. Here are some of the most often used bolt hardware nuts.
Hexagon Nuts
Hex nuts have a six-sided driving surface. They’re a common sort of nut used to connect wood and metal components with bolts of the same size and thread type.
Lock Nuts
Nylon lock nuts have a hexagonal head with an integrated nylon ring. When you tighten a lock nut onto a bolt, the threading of the bolt displaces or deforms the ring, causing friction and preventing loosening from slippage or vibration. A castle nut is a kind of locking nut that works by putting a pin or clip into a hole in the bolt. Rotation is restricted when notches etched into the nut come to rest on the pin.
Wing nuts
Wing nuts are designed to be tightened and loosened without the need of tools; the wings allow you to tighten and loosen them with your thumb and finger. These nuts are used to make adjustments and removals quick and easy. They may be found on drum sets, light stands, and other items that need to be adjusted on a regular basis.
Cap Nuts
Cap nuts, sometimes known as acorn nuts, are domed and feature a hexagonal driving surface. They are often hand installable. They screw onto the exposed threads of a bolt or threaded rod to protect them and provide a decorative look. Cap nuts may be found in projects like outdoor playsets and fences.
Nuts in squares
Because they have four relatively large driving surfaces, square nuts are easy to grab and spin. The nut’s form allows for a larger surface area to contact the fastening piece, providing better resistance to loosening and tightening. Use flat washers with square nuts to prevent the edges of the nuts from scratching the work piece.
Once you have constructed and successfully constructed you LNG process and system, another step is to put them into use. One of the most popular usage of LNG process and system is in the Cogeneration Power Plant.
https://www.gmsthailand.com/blog/what-is-bolts-and-nuts/ (https://www.gmsthailand.com/blog/what-is-bolts-and-nuts/)
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What is Department of Energy Business
Department of Energy Business Energy Ministry
The Ministry of Energy is in charge of energy acquisition, development, and administration, as well as other obligations that are stipulated in relevant legislation as the Ministry’s or its departments’ authority and duties.
The following departments, together with their respective tasks, report to the Ministry of Energy:
1. Minister’s Office: Responsible for and supportive of the Minister of Energy’s political missions in partnership with the cabinet, Parliament, and the general public; and manages responses to enquiries, explanations on motions, legislation, and other political issues.
2. Permanent Secretary’s Office: Create strategies and translate Ministry policies into action plans, allocate resources and manage staff to achieve Ministry objectives and missions, and coordinate international energy cooperation.
3. Department of Alternative Energy Development and Efficiency (DEDP): Promote energy efficiency, monitor energy conservation initiatives, undertake alternative energy research, and disseminate energy-related technologies.
4. Department of Energy Business (DOEB): Regulate energy quality and safety standards, including their environmental and security consequences, and continually improve standards to protect the interests of consumers. '
5. Department of Mineral Fuels (DMF): Promote and expedite energy procurement by allowing for the discovery and development of energy resources both in Thailand and beyond
6. Energy Policy and Planning Office (EPPO): Make recommendations on national energy policies and planning, establish energy measures, and implement preventive and corrective measures in the event of an oil shortage to ensure an adequate and efficient energy supply that is consistent with the country’s economic conditions.
The following are the State Enterprises under the Ministry of Energy:
1. Thailand’s Electricity Generating Authority (EGAT)
2. Metropolitan Authority for Electricity (MEA)
3. Provincial Authority for Electricity (PEA)
The following two autonomous public companies are administered by the Ministry of Energy:
1. PTT Public Company Limited (PTT)
2. Public Company Bangchak Petroleum Limited (BCP)
The following are the Public Organizations:
1. The Energy Fund Administration Institute (Public Organization), EFAI.
2. The Electricity Regulatory Board, abbreviated as the ERB
Department of Energy Business (DOEB)
As previously stated, the Department of Energy Business is a department within the Ministry of Energy that is responsible for quality and safety regulations for any energy business in the Kingdom of Thailand to ensure quality and safety standards are met by any manufacturers or organizations doing business with energy and fuels.
DOEB is in charge of releasing mandatory regulations and standards for business-entrepreneurs to comply with in order to do business in Thailand, as well as inspecting, verifying, and approving for related certificates and verifications for equipment, activities, and tools related to energy business, as well as updating and revising those standards and measurements on a regular basis in accordance with international agreements.
DOEB Missions:
1. Supervise the security, safety, trade quality and environment of the energy business in accordance with good governance principles.
2. To be the country’s energy business information center
3. Enhancing knowledge on energy for entrepreneurs and people
4. Promote the energy business to have fair competition protect consumers and people
5. Develop standards, quality, and safety of the energy business to meet international standards.
DOEB Visions:
Supervise the energy business according to international standards by good governance.
As DOEB is the regulator and enhancer for any Energy related business in Thailand, it is mandatory and necessary to align and work with DOEB for safe and complete operation of energy and natural fuel resources. Once your business and process system are registered and issued license by DOEB, you can commercially run your business and start the process right away.
https://www.gmsthailand.com/blog/what-is-department-of-energy-business/ (https://www.gmsthailand.com/blog/what-is-department-of-energy-business/)
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Welspun
Welspun Corp Limited (WCL) is one of world’s-leading welded line pipe manufacturer, and the flagship company of the Welspun Group. Over the last two decades, WCL innovative approach and, technical capabilities have helped deliver some of the path-breaking pipeline projects across the world such as Welspun Hot Pulled Induction Bends, Welspun Longitudinal (LSAW), Welspun Spiral (HSAW)
https://www.gmsthailand.com/category/welspun/ (https://www.gmsthailand.com/category/welspun/)
(https://f.ptcdn.info/828/075/000/r4isu0k84p1yv8J9UXB-o.jpg)
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Safety - Honeywell Gas & Flame Detection products
Safety
Honeywell Gas & Flame Detection products
Safety equipment plays an important role in every process of the factory. Various gas detection products and solutions are designed specially to protect your employees and factories. Moreover, it’s easy installation and low-cost maintenance.
https://www.gmsthailand.com/category/other-part-supply/honeywell-other-part-supply/safety-honeywell-other-part-supply/ (https://www.gmsthailand.com/category/other-part-supply/honeywell-other-part-supply/safety-honeywell-other-part-supply/)
(https://www.gmsthailand.com/wp-content/uploads/2021/11/sps-his-products-gas-and-flame-detection-fixed-industrial-detection-hero-tile.jpg)
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ธุรกิจร้านอาหาร เลือกบรรจุภัณฑ์เดลิเวอรี่ กล่องอาหารเดลิเวอรี่ อย่างไรให้โดนใจลูกค้า
(https://thaifoodpackaging.com/wp-content/uploads/2021/09/%E0%B8%98%E0%B8%B8%E0%B8%A3%E0%B8%81%E0%B8%B4%E0%B8%88%E0%B8%A3%E0%B9%89%E0%B8%B2%E0%B8%99%E0%B8%AD%E0%B8%B2%E0%B8%AB%E0%B8%B2%E0%B8%A3-%E0%B9%80%E0%B8%A5%E0%B8%B7%E0%B8%AD%E0%B8%81%E0%B8%9A%E0%B8%A3%E0%B8%A3%E0%B8%88%E0%B8%B8%E0%B8%A0%E0%B8%B1%E0%B8%93%E0%B8%91%E0%B9%8C%E0%B9%80%E0%B8%94%E0%B8%A5%E0%B8%B4%E0%B9%80%E0%B8%A7%E0%B8%AD%E0%B8%A3%E0%B8%B5%E0%B9%88.jpg)
เมื่อเทคโนโลยีสารสนเทศเข้ามามีบทบาทสำคัญต่อการดำเนินชีวิตของคนเราในทุก ๆ ด้าน การติดต่อสื่อสารที่สะดวกรวดเร็ว รวมถึงการใช้ชีวิตที่เร่งรีบตามการพัฒนาของเทคโนโลยี ทำให้พฤติกรรมการบริโภคปรับเปลี่ยนตามไปด้วย อาหารเดลิเวอรี่ที่มีบริการจัดส่งถึงที่ทำงานหรือส่งถึงที่พักของลูกค้า กลายเป็นธุรกิจที่ตอบโจทย์ความต้องการมากที่สุด
ธุรกิจร้านอาหาร กับเทรนด์การขายอาหารเดลิเวอรี่
การสั่งอาหารเดลิเวอรี่มารับประทานที่สำนักงานในช่วงพักเที่ยงหรือสั่งมารับประทานที่บ้าน เป็นธุรกิจบริการจากร้านอาหารที่กำลังเป็นเทรนด์นิยม เพราะนอกจากเหมาะกับการใช้ชีวิตที่ไลฟ์สไตล์ของคนในสังคม ซึ่งส่วนใหญ่มีความเรียบง่าย เน้นความสะดวกสบายและรวดเร็ว และยังเลือกใช้บริการไม่ยากในยุคนี้เพราะมีร้านอาหารมากมายที่เปิดให้บริการจัดส่งอาหารเดลิเวอรี่ควบคู่ไปกับการนั่งรับประทานอาหารในร้าน หรือเปิดเป็นครัวในบ้านไม่มีหน้าร้าน โดยรับสั่งอาหารทางออนไลน์หรือช่องทางอื่น ๆ ตามที่ทางร้านกำหนด
เมื่อธุรกิจอาหารเดลิเวอรี่ เป็นบริการที่ตอบโจทย์ความต้องการของกลุ่มลูกค้า การแข่งขันด้านการตลาดก็สูงตามไปด้วย ไม่เฉพาะเรื่องของรสชาติและเมนูอาหารที่โดดเด่นเท่านั้น แต่การเลือกบรรจุภัณฑ์เดลิเวอรี่ หรือกล่องเดลิเวอรี่ ก็เป็นส่วนประกอบสำคัญที่สามารถสร้างความพึงพอใจ ทำให้ลูกค้ากลับมาใช้บริการซ้ำหรือกลายเป็นลูกค้าประจำได้
เลือกบรรจุภัณฑ์เดลิเวอรี่ กล่องอาหารเดลิเวอรี่ อย่างไรให้โดนใจลูกค้า
บรรจุภัณฑ์เดลิเวอรี่ ถือเป็นหัวใจสำคัญของระบบจัดส่งอาหาร ไม่ว่าจะเป็นการจัดส่งอาหารให้ลูกค้าโดยพนักงานของทางร้าน หรือจัดส่งโดยผู้ให้บริการฟู๊ดเดลิเวอรี่ที่มีอยู่มากมาย เช่น แกร็บฟู้ด ฟู้ดแพนด้า ไลน์แมน สกู๊ตตาร์ โกเจ๊ก หรืออื่น ๆ สิ่งที่สามารถสร้างความพึงพอใจให้กับลูกค้าตั้งแต่แรกรับสินค้าก็คือบรรจุภัณฑ์หรือแพคเกจจิ้ง สำหรับการเลือกบรรจุภัณฑ์หรือกล่องอาหารเดลิเวอรี่ให้โดนใจลูกค้า มีดังนี้
1. การออกแบบและดีไซน์โดดเด่นสะดุดตา
บรรจุภัณฑ์หรือกล่องอาหารที่ใช้จัดส่งเดลิเวอรี่ ก็เปรียบเสมือนหน้าตาของร้านอาหารที่ลูกค้าอาจตัดสินใจเข้าไปนั่งรับประทานเพราะรู้สึกพึงพอใจหรือมั่นใจในรสชาติและคุณภาพของอาหารจากการจัดตกแต่งร้านที่มีเอกลักษณ์โดดเด่นสวยงาม กล่องอาหารเดลิเวอรี่พร้อมการบรรจุหีบห่อที่สวยงามสะดุดตา คือกลยุทธ์ด้านการตลาดที่สามารถสร้างความพึงพอใจให้กับลูกค้าได้ตั้งแต่แรกพบ
สำหรับร้านอาหารและการขายอาหารแบบเดลิเวอรี่ ปัจจุบันมีบรรจุภัณฑ์อาหารแบบสำเร็จรูปผลิตออกมาจำหน่ายหลากหลายรูปแบบและหลายประเภท ผู้ประกอบการสามารถเลือกซื้อและเลือกรูปแบบได้ตามความต้องการ หรือหากผู้ประกอบการต้องการออกแบบและสั่งผลิตจากโรงงานโดยตรง บริษัทผู้รับผลิตส่วนใหญ่ยังมีบริการแบบ One stop service คือให้บริการครอบคลุมตั้งแต่การออกแบบให้เหมาะสมกับประเภทอาหารหรือผลิตภัณฑ์ การเลือกวัสดุบรรจุภัณฑ์ และการผลิต
2. เลือกวัสดุบรรจุภัณฑ์อาหารที่เหมาะสมหรือเป็นมิตรต่อสิ่งแวดล้อม
กล่องอาหารเดลิเวอรี่ เป็นบรรจุภัณฑ์อาหารชนิดหนึ่งที่ผลิตจากวัสดุหลายประเภท คุณสมบัติของวัสดุแต่ละชนิดก็จะเหมาะสมกับอาหารและการใช้งานที่แตกต่างกันไป เช่น
- บรรจุภัณฑ์พลาสติก มีดีไซน์หลากหลายรูปแบบให้เลือกใช้ คุณสมบัติที่โดดเด่นของวัสดุบรรจุภัณฑ์ชนิดนี้ก็คือ มีน้ำหนักเบา คงทน สามารถวางเรียงซ้อนได้มากเหมาะกับอาหารประเภทน้ำ เนื่องจากป้องกันการซึมผ่านของน้ำได้ บางรูปแบบนอกจากบรรจุได้ทั้งของร้อนและเย็นแล้ว บางชนิดยังใช้อุ่นในไมโครเวฟได้ด้วย
- บรรจุภัณฑ์หรือกล่องอาหารทำจากโฟม เป็นกล่องอาหารที่ยังมีผลิตออกมาจำหน่าย เพราะใช้งานง่ายราคาไม่แพง แต่มีข้อด้อยที่ผู้ประกอบการร้านอาหารเดลิเวอรี่ไม่นิยมใช้คือไม่สามารถย่อยสลายได้เองตามธรรมชาติ และไม่ทนต่อความร้อน หากใช้บรรจุอาหารที่มีความร้อนก็อาจจะทำให้อาหารปนเปื้อนสารก่อมะเร็งได้
- บรรจุภัณฑ์ที่เป็นมิตรต่อสิ่งแวดล้อม เช่น กล่องอาหารทำจากกระดาษ กล่องอาหารเยื่อธรรมชาติและถุงกระดาษ คุณสมบัติที่โดดเด่นของบรรจุภัณฑ์ผลิตจากวัสดุธรรมชาติ สามารถย่อยสลายได้เองการเลือกใช้จึงช่วยลดภาวะสิ่งแวดล้อม และเป็นกล่องเดลิเวอรี่ที่ได้รับความนิยมมากที่สุด
3. บรรจุภัณฑ์ที่ช่วยรักษาคุณภาพอาหาร อาหารเดลิเวอรี่บางเมนูไม่เหมาะสำหรับการนำไปอุ่นให้ร้อน การเลือกใช้กล่องอาหารจึงนอกจากจะต้องรักษาคุณภาพอาหารให้คงที่จนถึงมือลูกค้า บรรจุภัณฑ์จะต้องช่วยยืดอายุการเก็บรักษาอาหารได้ด้วย
4. เป็นบรรจุภัณฑ์ที่ช่วยส่งเสริมการตลาด บรรจุภัณฑ์ที่ช่วยส่งเสริมการตลาด เช่น กล่องบรรจุอาหารที่มีการพิมพ์โลโก้หรือมีแบรนด์ของร้านพร้อมช่องทางการติดต่อติดอยู่ หรือมีรายละเอียดเกี่ยวกับปริมาณและส่วนประกอบในเมนูอาหารนั้น ๆ เพราะรายละเอียดเหล่านี้ไม่เพียงช่วยส่งเสริมการตลาดทำให้ลูกค้าติดต่อได้ง่ายและได้ฐานลูกค้าใหม่ ๆ เพิ่มมากขึ้นแล้ว แบรนด์หรือโลโก้ที่ติดอยู่กับบรรจุภัณฑ์ยังสร้างความมั่นใจให้กับลูกค้าในการเลือกใช้บริการเดลิเวอรี่อีกด้วย
5. บรรจุภัณฑ์ที่มีความมั่นคง แข็งแรง เหมาะกับการใช้งาน บรรจุภัณฑ์เดลิเวอรี่ การออกแบบหรือเลือกบรรจุภัณฑ์อาหารที่เหมาะสมกับประเภทของ
อาหาร รวมทั้งการออกแบบให้มีความสวยงาม ได้สัดส่วนที่ถูกต้องเหมาะสม ยังช่วยให้การจัดส่งอาหารสะดวกขึ้น สามารถป้องกันอาหารไม่ให้เกิดความเสียหายมากระหว่างการเดินทางได้เป็นอย่างดี
บรรจุภัณฑ์เพื่อสิ่งแวดล้อม สำคัญต่อธุรกิจอาหารเดลิเวอรี่อย่างไร
บรรจุภัณฑ์เพื่อสิ่งแวดล้อมผลิต คือบรรจุภัณฑ์เดลิเวอรี่ที่ผลิตจากวัสดุธรรมชาติ เมื่อนำมาใช้แล้วปลอดภัยต่อผู้บริโภค ไม่ส่งผลกระทบสภาพแวดล้อม โดยบรรจุภัณฑ์เพื่อสิ่งแวดล้อมที่ผู้ประกอบการร้านอาหารนิยมใช้ มีทั้งแบบสำเร็จรูปที่โรงงานผลิตออกมาวางจำหน่าย และสั่งผลิตตามรูปแบบที่ต้องการ ความสำคัญของบรรจุภัณฑ์เพื่อสิ่งแวดล้อม ต่อธุรกิจขายอาหารเดลิเวอรี่ มีดังนี้
1. สร้างความรู้สึกมีส่วนร่วมต่อการอนุรักษ์สิ่งแวดล้อมให้กับลูกค้า การออกแบบหรือเลือกใช้วัสดุบรรจุภัณฑ์เดลิเวอรี่จากธรรมชาติ มีส่วนสำคัญในการช่วยลดปัญหาภาวะโลกร้อนและมลภาวะเป็นพิษต่าง ๆ ได้เป็นอย่างดี และจากการรณรงค์ให้ตระหนักถึงปัญหาสิ่งแวดล้อมของภาครัฐ ทำให้การอนุรักษ์สิ่งแวดล้อมเป็นเทรนด์ที่กำลังมาแรง เมื่อผู้ประกอบการเลือกใช้บรรจุภัณฑ์ที่เป็นมิตรต่อสิ่งแวดล้อม ก็จะส่งผลให้ลูกค้าหรือผู้บริโภครู้สึกมีส่วนร่วมต่อการอนุรักษ์จากการใช้กล่องเดลิเวอรี่ที่ผลิต่จากวัสดุจากธรรมชาติซึ่งสามารถย่อยสลายได้เอง
2. การใช้บรรจุภัณฑ์รักษ์โลก สร้างจุดขายให้กับธุรกิจ กล่องเดลิเวอรี่ ผลิตจากวัสดุธรรมชาติเป็นบรรจุภัณฑ์รักษ์โลกที่มีลักษณะโดดเด่นมีเอกลักษณ์ในตัวของบรรจุภัณฑ์อยู่แล้ว เมื่อสั่งผลิตและมีการออกแบบที่สวยสะดุดตา ก็สามารถสร้างจุดขายหรือสร้างภาพลักษณ์ให้กับธุรกิจ ทำให้แบรนด์หรือร้านอาหารของเราเป็นที่จดจำและได้รับความนิยมจากผู้บริโภคได้ง่ายจากภาพลักษณ์ที่โดดเด่นของธุรกิจ
3. การใช้บรรจุภัณฑ์เดลิเวอรี่เพื่อสิ่งแวดล้อมช่วยลดปริมาณขยะ ปัญหามลภาวะหรือปัญหาสิ่งแวดล้อมเป็นพิษ ส่วนหนึ่งเกิดจากขยะบรรจุภัณฑ์ที่ไม่สามามารถย่อยสลายได้ตามธรรมชาติ หรือต้องใช้ระยะเวลาในการย่อยสลาย และวัสดุบรรจุภัณฑ์บางชนิดเมื่อกำจัดผิดวิธีเช่นการเผาทำลายยังก่อให้เกิดมลพิษ การเลือกใช้บรรจุภัณฑ์เดลิเวอรี่เพื่อสิ่งแวดล้อมนอกจากช่วยลดปริมาณขยะแล้ว ยังเป็นการรับผิดชอบต่อสังคมส่วนรวมซึ่งเป็นการสร้างภาพลักษณ์ที่ดีให้กับธุรกิจอีกทางหนึ่งด้วย
4. เป็นการสร้างกลยุทธ์ด้านการตลาด การขายอาหารโดยเฉพาะอาหารเดลิเวอรี่ เป็นธุรกิจที่มีการแข่งขันด้านการตลาดสูงมาก เพราะอาหารเป็นสิ่งที่คนต้องบริโภคทุกวัน การออกแบบและสั่งผลิตบรรจุภัณฑ์อาหารเดลิเวอรี่รูปแบบใหม่ ๆเพื่อให้ได้รูปแบบที่แตกต่าง ถือเป็นการสร้างกลยุทธ์เพื่อใช้สู้กับคู่แข่งด้านการตลาดได้อย่างเห็นผล เพราะนอกจากเป็นการส่งเสริมการขายและสร้างการมีส่วนร่วมของผู้บริโภคแล้ว ยังช่วยให้ร้านอาหารของเราเป็นที่จดจำของลูกค้าได้อย่างมีประสิทธิภาพ
5. สร้างแบรนด์ผ่านบรรจุภัณฑ์อาหารเดลิเวอรี่ กล่องอาหารหรือบรรจุภัณฑ์อาหารจากวัสดุธรรมชาติ มีหลากหลายรูปแบบและหลายขนาดให้เลือกใช้ เช่น กล่องอาหารกระดาษ หรือถุงกระดาษ นอกจากสามารถเลือกใช้ให้เหมาะสมกับประเภทของอาหารแล้ว การสร้างแบรนด์ผ่านบรรจุภัณฑ์อาหารเดลิเวอรี่เหล่านี้ทำได้โดยการพิมพ์โลโก้ลงบนสติกเกอร์ สายคาด หรือสกรีนบนฝากล่อง และยังสามารถใส่ที่อยู่เบอร์ติดต่อเพิ่มเติมลงไปได้อีกด้วย ซึ่งช่วยให้ลูกค้าจดจำแบรนด์หรือจดจำร้านอาหารของเราได้ง่าย
6. บรรจุภัณฑ์อาหารจากวัสดุธรรมชาติมีน้ำหนักเบา หัวใจสำคัญของธุรกิจอาหารเดลิเวอรี่ ก็คือความรวดเร็วในการจัดส่งสินค้าเพราะนอกจากเรื่องของการรักษาคุณภาพของหารให้คงรสชาติไม่แตกต่างไปจากการเดินทางมานั่งรับประทานที่ร้านแล้ว กรณีที่ทางร้านบริการจัดส่งอาหารให้กับลูกค้าโดยไม่คิดค่าใช้จ่ายเพิ่ม การเลือกใช้กล่องเดลิเวอรี่จากวัสดุธรรมชาติยังมีน้ำหนักเบา ช่วยให้ง่ายต่อการจัดส่งและยังขนส่งได้ครั้งละมาก ๆ ทำให้ลดต้นทุนในการจัดส่งได้ด้วย
7. ปลอดภัยต่อสุขภาพของผู้บริโภค กล่องอาหารเดลิเวอรี่ที่เป็นมิตรต่อสิ่งแวดล้อม ผลิตจากวัสดุธรรมชาติ นอกจากการออกแบบให้มีความแข็งแรงทนทาน สามารถป้องกันการซึมของอากาศ น้ำ หรือน้ำมัน ใช้แล้วไม่เป็นสนิม เมื่อถูกความร้อนไม่ทำให้เกิดสารปนเปื้อน ปลอดภัยต่อสุขภาพของผู้บริโภค
8. ตอบโจทย์ความต้องการของสังคม การที่องค์กรภาครัฐจัดกิจกรรมรณรงค์ให้คนในสังคมเห็นความสำคัญของของปัญหาสิ่งแวดล้อม ส่งผลให้ผู้บริโภคโดยเฉพาะการสั่งอาหารเดลิเวอรี่เห็นความสำคัญของบรรจุภัณฑ์เดลิเวอรี่ที่ผลิตจากวัสดุธรรมชาติ เพื่อช่วยลดปัญหาขยะจากบรรจุภัณฑ์ ดังนั้นการที่ผู้ประกอบการร้านอาหารเลือกใช้กล่องอาหารกระดาษ จึงส่งผลดีและสามารถเพิ่มยอดขายให้กับธุรกิจได้ เพราะตอบโจทย์ความต้องการของสังคม
สรุป การพัฒนาของเทคโนโลยี ส่งผลให้การขายอาหารเดลิเวอรี่ เป็นธุรกิจที่กำลังมาแรงเนื่องจากเหมาะกับไลฟสไตล์ของคนในสังคมที่ต้องทำงานแข่งกับเวลา รวมทั้งการใช้ชีวิตที่เรียบง่าย เน้นความสะดวกสบาย รวดเร็ว และให้ความสำคัญกับการดูแลสุขภาพ กล่องอาหารเดลิเวอรี่หรือบรรจุภัณฑ์เดลิเวอรี่ ที่ผลิตจากวัสดุธรรมชาติจึงถือเป็นหัวใจสำคัญของธุรกิจ การเลือกบรรจุภัณฑ์เดลิเวอรี่ กล่องอาหารเดลิเวอรี่ ให้โดนใจลูกค้าก็คือ การออกแบบและดีไซน์โดดเด่นสะดุดตา เลือกวัสดุบรรจุภัณฑ์อาหารที่เหมาะสมหรือเป็นมิตรต่อสิ่งแวดล้อม ช่วยรักษาคุณภาพอาหาร เป็นบรรจุภัณฑ์ที่ช่วยส่งเสริมการตลาด และมีความมั่นคงแข็งแรงเหมาะกับการใช้งาน
https://thaifoodpackaging.com/blog/food-delivery-with-restaurant/ (https://thaifoodpackaging.com/blog/food-delivery-with-restaurant/)
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Flowserve - valves are ready to service all over the world.
Flowserve
Our valves are designed with specific functions to match with our customer’s requirement.
Flowserve
valves are ready to service all over the world. Moreover, we do trust in safe environment, so we have many expert engineers to help you with useful information.
https://www.gmsthailand.com/category/flowserve/ (https://www.gmsthailand.com/category/flowserve/)
Flowserve Plug Value for oil & gas isolation
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Lubricated Plug Values - Twin Isolation
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Flowserve Plug Valve for oil&gas isolation
For the biggest challenges of fluid motion control, customers worldwide rely on the engineering, project management and service expertise of . We Flowserve Plug Valve deliver more than the most complete portfolio of reliable valves, pumps and seals available.
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With global team, which is more than 18,000 employees in 55 countries, we can provide an ultimate solution from project planning to the maintenance process with the most sophisticated technology by Flowserve Plug Valve. As a professional team, we are able to exceed your expectation and willing to underdo with any failure.
Due to long-established reputation since 1896, Serck Audco came out with newest valve design ,manufacturing techniques and well-rounded service from around the world. Our products are used widely in oil and gas , food, chemical and mining industries.
Why Select a Flowserve Plug Valve?
- PRESSURE BALANCED PLUG VALVES
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PRESSURE BALANCED PLUG VALVES
Large seating area enhances the Super-H resistance to erosion.
The wide area maximizes the effectiveness of sealant, so that any unlikely seat damage can solve injecting Serck Audco Sealant, restoring the valve zero leakage bubble tight shut-off capabilities without the need of seats replacement.
Moreover, Sealant can inject with the valve in any position and also under pressure, making the valve in-line maintainable.
- BALL VALVES
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BALL VALVES
The thin seating area can be damaged by the erosion action of the media and the particles contained in it.
Difference between Sealant for Plug Valve and Sealant for Ball Valve
Sealants for Ball Valves valve generally designs to stop leakages on damaged ball valves. To achieve this and since Ball Valves have thin seating areas, sealants are thicker and include a higher percentage of solid fillers in an effort to plug seat damages and not be washed away by pressure.
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Difference between Sealant for Plug Valve and Sealant for Ball Valve 1
Futhermore, Sealants for Flowserve Plug Valve designs to provide general lubrication and bubble tight sealing performance. Since plug valves have relatively wide seating areas, sealants can be thinner and still provide zero leakage over several operations.
Using a Ball Valve sealant on a Plug Valve is not recommended. Moreover,The thicker nature (and high percentage of solid fillers) of a Ball Valve sealant will increase operating torques due to the wide contact area between plug and body and even lead to valve jamming if the sealant dries up.
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Difference between Sealant for Plug Valve and Sealant for Ball Valve 2
Flowserve Plug Valve Products
1) Lubricated Plug Valves – SUPER H
BRAND: Serck Audco
The Super-H Lubricated Plug Valve is a rugged, pressure balanced plug valve designed for demanding oil and gas isolation applications where bubble tight shut-off and reliable operation are critically important.
Super-H Design
Basic design advantages of Flowserve Plug Valve such as metal-to-metal seats and a wide seating area, along with competitive pricing, have made plug valves the product of choice when the valve operates in a difficult or dirty service and/or needs to open against full differential pressure. The robust metal-to-metal seats ensure long valve life on any service, even in presence of solid particles in the line media.
Features and Benefits
Benefits
- Certainty of zero leakage sealing down the line, even with damaged metal seats.
- Certainty of operation with low and consistent torque which is stable over long periods of time.
- Minimal maintenance regime.
- Full in-line maintainability even under full pressure and without any need of shut down.
- Assured sealing to atmosphere
How It Is Achieved
- Precise seat mating procedures.
- Effective sealant injection system combined with wide seating areas.
- Pressure balanced plug as standard, with option of Protected Pressure balance®
- Super LoMu Anti Friction Treatment on plug and stem.
- Precise factory set plug loading
- Provision for sealant injection for the seats
- Provision for stem packing re-injection
- Independent stem sealing design that can meet stringent fugitive emissions requirements.
- All pressure seals in fire safe metal or graphite.
Design Range
- Super-H valves are available in Regular, Short or Venturi, Pattern, in accordance with API 6D, API 599 and BS 5353. The different patterns vary in regard to face-to-face dimension and port area for a given size of valve.
- Size Range:
- DN 15 to 1050
- NPS ½ to 42
- Pressure Class Range:
- PN 20 to 420
- Class 150 to 2500
- API 2000 to 10000
Standard
- API 6D – Specification for pipeline valves
- API 6A – Specification for wellhead equipment
- ISO 14313 – Petroleum and natural gas industries-Pipeline valves
- ISO 10423 – Petroleum and natural gas industries-Wellhead equipment
- API 599 – Metal plug valves – flanged, threaded and welding ends
- BS 5353 – Specification for steel plug valves
- ANSI B16.10 & BS 2080. – Face-to-face and end-to-end dimensions
Sample Applications
- Bypass Equalizing Valve : To resist the erosion caused by full differential pressure openings on a transmission line, it will seal to protect the main line valve
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Bypass Equalizing Valves
- High Pressure Gas Isolation : Bubble tight shut-off on one of the more searching medias
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High Pressure Gas Isolation
- Underground Storage : Protected metal seating to resist impurities and give zero leakage even on the highest pressures
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Underground Storage
- Slurry Isolation Extremely abrasive services, a robust valve with no cavities
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Slurry Isolation
Reference
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2) Lubricated Plug Valves – DOUBLE ISOLATION
BRAND: Serck Audco
The Double Isolation Lubricated Plug Valve is a reliable, double isolation plug valve with two independent obturators in a single body. It is ideal for double block and bleed applications.
Design Features
- Same face-to-face as one valve.
- In-line emergency stem sealing
- In-line sealant injection point
- Choice of mounting positions for actuators and handwheels.
- Bleed port.
- Bleed valve flange interface
Benefits
- Improved plant and personnel safety assured by a double isolation design that allows the operator to verify valve isolation before carrying out maintenance
- A cost-, space- and weight-saving alternative to a double block and bleed system using two valves in a series
- Ease of installation from a compact design with the same face-to-face dimensions as a single valve, often replacing it without the need for pipe work modifications
- Greater process control via a pressure balanced design that provides a true bubble-tight double isolation capability within a single valve body
https://www.gmsthailand.com/product/flowserve-serck-audco-plug-valve-for-oilgas-isolation/ (https://www.gmsthailand.com/product/flowserve-serck-audco-plug-valve-for-oilgas-isolation/)
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LUBRICATED PLUG VALVES – TWIN ISOLATION
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The Twin Isolation Lubricated Plug Valve is a reliable, double isolation plug valve with two independent obturators in a single body. It is ideal for double block and bleed applications.
https://www.gmsthailand.com/product/lubricated-plug-valves-twin-isolation/ (https://www.gmsthailand.com/product/lubricated-plug-valves-twin-isolation/)
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Cameron Surface a leading provider of products and equipment
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Cameron Surface
for the onshore, offshore and subsea oil and gas industry. We specialize in system design and project management for Onshore and offshore production.
https://www.gmsthailand.com/category/cameron-surface/ (https://www.gmsthailand.com/category/cameron-surface/)
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Lithium Bromide Absorption Chiller for waste heat recovery
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Absorption Chiller is an equipment which uses heat source from natural gas ,diesel, solar energy and waste heat to produce a cooling system. As its practical function, absorption chiller is normally installed in air-conditioning building such as factory, office, hospital or airport. Especially, the machine utilize the waste heat recovery from gas engine or gas turbine.
Although the electricity is in limited situation, absorption chiller also can activate. Furthermore, it only consumes a small amount of electric energy in the systems, compared to electric chillers.
During the process, the absorption chiller uses a lithium bromide solution (LiBr) as the absorbent and water as the refrigerant. The reason a lithium bromide because of not being a hazardous chemical. Another outstanding characteristic is non-CFCs and non-HFCs which are harmful to the environment.
Here are more advantages of Absorption chiller: Driving power from Heat Energy, Less electric energy consumption, Easy maintenance, Low maintenance costs, Less noise and vibration, Non-CFCs or Non-HFCs refrigerant and Environmental-friendly.
Principle
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Firstly, weak solution in the absorber which is suitable for concentration mixed with lithium bromide solution and water is pumped through the heat exchanger. Then, It becomes the intermediate solution before flowing into the generator separating the water and lithium bromide solution. The generator utilizes the heat energy from waste heat such as Flue gas, Steam or Hot water.
In the Generator, the water will be changed to vapor and leave the lithium bromide solution, but it will not be left as a waste. It will be formed as a liquid and drop to bottom of the generator. The liquid flows down to preheat the weak solution in the heat exchanger and becomes strong solution. Then, it flows back to spray over the absorber to absorb the vapor for next process again.
Meanwhile, the vapor which left from lithium bromide solution in generator flows into the condenser. The solution will be cooldown by the cooling water, then it will be condensate to the refrigerant. It flows down to the evaporator due to the vacuum condition which made the water boiling temperature becomes low.
In the Evaporator, 12°C chilled water which returns from operation system flows into the evaporator. The unwanted thermal energy will be extracted by spraying refrigerant over the chilled water pipe in the evaporator. Therefore, the chilled water temperature will be decreased to 7°C.
Finally, after the refrigerant water extracted unwanted thermal from chilled water, it will become the vapor again as low boiling temperature under the vacuum condition in the evaporator. After that, the vapor will be absorbed by strong solution and become weak solution for the new cycle again.
Shuangliang Waste Heat Recovery Solution Provider
Shuangliang has dedicated to the study of industrial waste heat recovery over 3 decades. As endless attempt, Shuangliang is gradually developing from as equipment supplier into a system provider.
About 60% of all energy generated in the world is left as a waste heat. Unfortunately, most of the waste heat will be degraded as traditional heat recovery technologies can’t activate effectively. From this point, Shuangliang Eco-Energy System Co., Ltd. wants to solve this problem by turning it to useable energy.
Shuangliang Eco-Energy Systems Co., Ltd. has been founded since 1982. According to the expertise, it is the first and only listed company in the absorption chiller industry. Eventually, the company joined with Shuangliang Group, a large enterprise that provides manufacturing, chemical and materials, and hotel services.
Product
- Flue Gas Lithium Bromide Absorption Chiller
Flue gas absorption chiller is applied as an important role of the tri-generation system. Normally, gas engine produces electricity while exhaust heat drives an energy of absorption chiller. According to this process, the waste heat from gas engine can provide cooling capacity for any communities and buildings.
As a combination of cooling, heating, and power generation system, the flue gas absorption chiller can increase capacity utilization and efficiency up to 85%. Moreover, the absorption chiller enhances power supply safety from the grid and leads more electricity saving. From several advantages, the absorption chiller can enhance environmental protection and sustainably economic development.
- Direct Fired Lithium Bromide Absorption Chiller
Due to the increase of electricity price and continual concern to environmental issues, Shuangliang eco-energy develops the high energy-efficiency. Absorption chiller is energized by the heat from directly burning light oil, heavy oil, industrial gas, or natural gas. By using heat of different levels, the direct fired absorption chiller can produce chilled water temperature from 5 °C to 7 °C which mostly used in the air conditioning system.
- Steam Lithium Bromide Absorption Chiller
The Steam Lithium Bromide Absorption chiller is one of Shuangliang famous models. Steam pressure with 0.01-0.15 MPa can provide a cooling capacity of 350~11630 kW. Also, 5°C to 7°C chilled water is suitable for the central air conditioning system or industrial process.
Due to its advantage, waste steam from the steam turbine in power generation can be reused as an energy for absorption chiller, also steam from the boiler
Especially, Shuangliang double-effect absorption chiller is in the most leading manufacturer. With high COPs of 1.43, it can provide high efficiency, low energy consumption and low-operating costs.
- Hot Water Lithium Bromide Absorption Chiller
With Shuangliang standard specifications, the temperature range of hot water about 90°-130°C is applied as a main role of the hot water single stage and two-stage absorption chillers. Moreover, Shuangliang standard specifications are available for suitable temperature and customer’s requirement.
The cooling capacity of hot water absorption chiller is between 350~6890 kW. As the chilled water temperature is about 5 °C –7 °C which is useful for air conditioning system and industrial process.
To reuse waste heat recovery, utilizing waste hot water from gas engine or other industrial process in hot water absorption chiller is one of effective ways to save energy, reduce electricity cost and saves considerable amount of operating costs.
https://www.gmsthailand.com/product/lithium-bromide-absorption-chiller/ (https://www.gmsthailand.com/product/lithium-bromide-absorption-chiller/)
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Citech Ltd. developed specifically for the offshore oil and gas industry
CiTECH Ltd
are an acknowledged leading supplier of Waste Heat Recovery Units (WHRU’s). The CiBAS WHRU has been developed specifically for the offshore oil and gas industry as an all-in-one package with built in silencer and bypass sleeve for flow isolation and control. When compared to other types of WHRU, the CiBAS range offers a 30% to 50% reduction in overall weight and space envelope. The unique and patented design of CiBAS alleviates the need for a separate silencer, isolation and control dampers together with operational and bypass stacks.
https://www.gmsthailand.com/category/citech/ (https://www.gmsthailand.com/category/citech/)
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Wellhead Xmas Tree
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Cameron’s MH Series hydraulic actuators are designed to be used with most manufacturers’ gate valves. Recommended for high-thrust applications required for large-bore and high-pressure valves – when there is no gas source or when the well gas is too sour – the MH Series offers a reliable and robust actuator that can be installed in harsh and remote environments.
Cameron’s MH Series hydraulic actuators
- Fail-Safe Design
- Rising and Non-Rising Stem Designs
- Non-Pressurized Actuator Housing
- Superior Piston Design
- Cameron’s Seal Technology
- Fixed rift Adjustment
- Corrosion-Resistant Materials
- Ease of Maintenance
- Accessories
Wellhead Xmas Tree ‘s Standard Actuator Data
- API 6A actuators for use with 1-13/16” through 9-1/16” nominal gate valves
- API 6A Appendix F, PR-2 qualified
- Temp -20° F to 250° F (-29° C to 121° C) standard temperature rating (other temperatures available)
- 3” to 9” standard piston sizes for above referenced valve groups
- 6000-psi maximum operating pressure
- Wide range of options and accessories available
Wellhead Xmas Tree ‘s Standard Bonnet Data
- Standard stem and bonnet materials API material/temperature class dependent
- PSL-1, 2, 3, and 4 available
- Standard bonnet backseat test port provided
- Standard packing leak indicator port provided
https://www.gmsthailand.com/product/wellhead-xmas-tree/ (https://www.gmsthailand.com/product/wellhead-xmas-tree/)
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Air cooled condenser (ACC) for thermal power plant
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DIRECT AIR COOLED CONDENSER SYSTEM
In regions which are remote from water resources, air cooled condenser (ACC) is an important role of a condensing equipment.
Air Cooled Condenser utilizes ambient air to remove heat out of exhaust steam for thermal or biomass power plants.
Generally, applying another type in an insufficient-water area needs to make a water reservoir to collect the water for serving cooling tower. Thus, Air cooled condenser (ACC) will help reduce capital cost of such a water reservoir, save water consumption cost during operation. Also, it solves the problem of diverting water from the community.
In the thermal power plants, exhaust steam from the steam turbine flow into the air cooled condenser (ACC) where the condensation occurs. Then the condensate-water returns to the boiler in a closed loop. Meanwhile the exhaust steam coming from the turbine is at a low pressure, the Air Cooled Condenser works at pressure as vacuum to avoid the pressure drop increase and impact to the efficiency of power generation, and then the non-condensable gases will be removed continuously by the air evacuation system.
Configuration and Scope of Shuangliang Air Cooled Condenser
Scope normally covers equipment and ducts from turbine exhaust to inlet of condensate pump, mainly including:
- Tube bundle
- Air supply system
- Air evacuation system
- Condensate system
- Cleaning system
- Exhaust steam ducting system
- Supporting structure
- Draining system
- Electric system
- Instrument & control system
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Principle of Air cooled condenser
The working principle of Air Cooled Condenser is to distribute the exhaust steam from the steam turbine straightly to the stream condensers in several rows through ducting. At the same time, the large axial-flow fans intake air and sweep over the tube bundles externally to carry away heat. In tube bundles, the exhaust steam gradually changes to condensates and is accumulated in the condensate tank through the bottom headers. Moreover, the vacuum of the whole Air cooled condenser (ACC) covers by the air evacuation system. For this reason, the steam turbine can activate smoothly and confirm power generation efficiency.
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Air cooled condenser process
The steam condensers are consisted of two types of tube bundles: parallel- flow and counter-flow types.
In the parallel-flow tube bundles, most of the steam is condensed, meanwhile the non-condensing gas is extracted in counter-flow tube bundles which they are connected through the bottom headers.
Additionally, the advantages of the direct air cooled condenser system (ACC) is occupying less floor area, various anti-freezing methods and flexible arrangement.
Technical and Advantage of Shuangliang Air cooled condenser
Single-Row Tube
Shuangliang Single-Row Tube is one of the best selective innovations which is applied in Air Cooled Condenser (ACC), characteristics designed by welded large flat tube and aluminum snake-like fins, are rolled from single-sided aluminum cladded carbon steel strip. The flat tubes and fins are connected by brazing.
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Shuangliang Single-Row Tube design
1. High heat transfer efficiency
The heat exchange at both sides of tube bundle is fully activating, mean to the exhaust steam has large size of flow area and very low-pressure loss, so the heat transfer efficiency is extremely high.
2. Strong resistance to corrosion
To have strong corrosion resistance, the external surface of base tube for the tube bundle is clad with aluminum alloy, the heat exchange fins of tube bundle also aluminum alloy spray coating, even after those materials are processed, aluminum oxide protective layer will still be formed thereon to achieve good corrosion resistance.
3. High strength and good cleaning ability
Welding several single-row fin tubes and tube-sheet was also applied in order to strengthen all the structures. Moreover, this process would apply for facilitate installation and transportation. Another distinctive characteristic, using straight-line type in single-row tube fins are easy to wash with high-pressure water without any deformation.
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4. Good anti-freezing performance
In order that the condensate flows more smoothly, we create a large length-width ratio of the base tube. Furthermore, this specific characteristic is able to reduce the extent of sub-cooling and the risk of tube freezing in winter.
5. Weld seam position
The weld seam is on the arc of the base tube of the single-row tubes, The arc spray aluminum coating has the better welding strength.
Shuangliang no need to be worried about the leak occurring during the operation since it can be repaired immediately without removing the entire tube bundle or replacement. Above all, we do believe in Easy maintenance and low maintenance costs.
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The weld seam is on the arc of the base tube
6. Single-Row Tube Bundle Fatigue test
Evacuated by vacuum pumping, the tube bundle will be reached to vacuum condition and then returned to normal pressure. After that, cycle tests will evaluate the number of cycles (fatigue life) in which the change occurs abruptly in the single-row tube.
To ensure reliance of Shuangliang Air cooled condenser (ACC), the qualified value of the product fatigue life should be more than 1,000 times and more than ten times the actual fatigue times. Due to qualified value, our customers can assure that our product’s safety lasts the 30-year design life.
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THREE MAJOR TEST DEVICES
1. Performance testing device on tube bundles of Air cooled condenser (ACC)
The Performance testing device on tube bundle as applies for experimenting heat exchange performance of various types of fined tube bundle structure and online random test of finished products.
After pressure and temperature of the steam are gradually reducing, the testing device will simulate several operating backpressures of the steam turbine, measure the heat exchange performance and resistance loss of the tube bundle. It also obtains the heat exchange coefficient and air resistance of tube bundle at different air speed and internal flow resistance of tube bundle at different steam flow speed.
Furthermore, to evaluate actual performance of tube bundle, the testing device is also utilized for examining thermal performance of tube bundle.
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2. The unique environmental test laboratory : 1×4 Air cooled condenser (ACC) environmental test device
Shuangliang Air cooled condenser is available for worldwide. It can simulate the summer operating conditions and winter operating conditions of Air cooled condenser (ACC), the unique environmental test laboratory will imitate ambient temperature of 50°C~-25°C. Therefore, there are two operating conditions to test in different situations.
One is the summer operating condition. It’s for testing the heat transfer performance of the tube bundles of the Air cooled condenser (ACC) which provides the basis for the design of the actual Air cooled condenser (ACC).
The other is the winter operating condition. It is for evaluating whether the control program of Air cooled condenser (ACC) is valid for antifreeze protection measures during operating conditions such as the machine functional of start, stop and low load operating conditions. Finally, it could test the minimum antifreeze steam flow under different temperature conditions.
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Environmental test device
3. The unique large full-performance test bed: Hot-state test device for one unit of 1000MW Air-cooled condenser (ACC)
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The unique large full-performance test device can simulate the main operating conditions of power station for the performance test, heat exchange performance, system reliability, stability, and economy of Shuangliang Air Cooled Condenser (ACC). Particularly ensure the ACC can operate capacity at summer full load and winter anti-freezing running reliability.
https://www.gmsthailand.com/product/air-cooled-condenser-acc/ (https://www.gmsthailand.com/product/air-cooled-condenser-acc/)
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LNG pressure regulator unit
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LNG Station LNG pressure regulator unit
A system which adjusts the pressure of gas and fluid to an appropriate level is Pressure regulator unit (PRU). The process depends on negative feedback from the controlled pressure. This regulator may be used as an integral device for liquid and gas which includes a pressure setting, a sensor and a restrictor all in one body.
Application of Pressure regulator unit (PRU)
The primary function of a pressure reducing regulator is to control the flow of gas through the regulator to a desired value while sustaining an output pressure constantly. While the load flow reduces, the Pressure regulator unit flow will reduce too. In contrast, While the load flow rises, the regulator flow rises to sustain controlled pressure from gas shortage in the pressure system. Generally, the controlled pressure won’t be much different from the set point for a wide range of flow rates. Moreover, the flow through the regulator is expected to be constant and the regulated pressure won’t be oscillated excessively.
The pressure regulating system includes emergency shut-off valve, multi-stage heat exchanger, multi-stage pressure regulator, relief valve, intelligent flow meter, bypass valve and control system, etc. The control system includes pressure, temperature, flow display and safety interlocking. The heating system includes gas boiler, hot water circulation pump or electric heater.
A high differential pressure appears in LNG pressure regulator skid. Firstly, this device connects with LNG vaporizer by hose and quickly connector. After that, LNG which changes to NG runs into pressure regulating unit through the high-pressure hose, ball valve, filter, and cut-off valve. The pressure will be about 1.0 ~ 4.0Mpa depending on customer requirement by pressure regulator.
The secondary regulator will control the gas pressure following to customer’s demand. In case of low pressure of the outlet, the third pressure regulating will be necessary.
The gas flow meter will measure NG that passes it. Finally, it will be sent to middle pressure pipeline. Normally, LNG Pressure regulating unit can be assembled by contractor at the site. Furthermore, Gms Interneer can provide pressure regulating unit skid for portable platform as temporary station.
https://www.gmsthailand.com/product/pressure-regulator-unit/ (https://www.gmsthailand.com/product/pressure-regulator-unit/)
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LNG Ambient Air Vaporizer (AAV)
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GMS has responded the continuous growth of LNG industry and seek out leading technology to serve our customer’s demand in developing LNG business such as, LNG storage tank, vaporizer, pressure regulating unit (PRU) or even in entire LNG station and others.
LNG Ambient Air Vaporizer (AAV) that we provide comes from leading technology manufacturers with international certification that has been accepted all over the world and competitive price. The vaporizer material and design comply ASME Boiler and Pressure Vessel Code.
Overview – LNG Ambient Air Vaporizer (AAV)
About the vaporizer, Gms Interneer offers low-high pressure range. The vaporizer is designed for specific customer’s requirements.Moreover, our product ensures that low temperature gas would not get into the pipeline. Moreover, the consulting service for LNG equipment design, standard and DOEB authorization is available for our customers.
Ambient air vaporizers are relative heat exchangers which vaporize liquified gas by using absorbed heat from the ambient air. Liquid gas passes through a number of interconnected tubes in various series and parallel paths. Due to this simple principle of operation, these vaporizers have no movable parts which results in zero OPEX and low maintenance costs. Plus, Ambient air vaporizers are in a wide range of application throughout the industry.
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Application of LNG Ambient Air Vaporizer (AAV)
The function of the LNG ambient air vaporizer is transforming liquified natural gas (LNG) to natural gas (NG). Heat transfer mechanism in the vaporizer is ambient air convection heat transfer to heat up LNG in liquid state to become vapor state or natural gas. After, the natural gas shall be provided to customers for utilizing as fuel in industrial or power plant. Ambient air vaporizers represent the most cost-effective equipment to vaporize or re-gasify liquid cryogenics.
The components of vaporizer that is important for heat transfer between LNG and ambient air is tubes cladded with aluminum for enhancing heat transfer area as shown in the picture. This feature can help the vaporizer to be more compact.
The ambient air vaporizer can categorize as application features following
- Low pressure ambient vaporizer for the pressure is not exceed 40 Barg
- High pressure ambient vaporizer for the pressure is more or equal to 40 Barg
- Fan forced vaporizer for controlling air flow rate efficiently
- Mobile vaporizer in frame for locatable application
- Pressure building vaporizers for controlling pressure in a storage tank
Another alternative
Fan assisted Vaporizer or Fan Ambient temperature vaporizer is very useful for any application. It provides increased run-times for vaporizer by increasing substantial flow rate in smaller footprints. As air forced upon the fins ice accumulation takes place, which reduce defrost cycle and improves ability for frequent switching of LNG fan forced Vaporizer. Contrasted from Natural ambient atmospheric vaporizers, Fan Assisted Vaporizers are covered from all sides with inverted fan on the top. This high velocity fan forced fresh air from top, which substantiates downward flow of heavy air further and almost doubles the regasification capacity of Vaporizer. Fan forced Vaporizer have been proved that they are worth in congested industrial units where Natural wind draft cannot accessible.
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Project Reference
LNG-IND of EA Bio Innovation Project and LNG-IND 2 Stations AMITA Technology Thailand Project
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https://www.gmsthailand.com/product/lng-ambient-air-vaporizer-aav/ (https://www.gmsthailand.com/product/lng-ambient-air-vaporizer-aav/)
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LNG storage tank for Permanent LNG station
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LNG station facilitates for storing LNG, changing to natural gas, and regulating pressure prior to transfer to customers. LNG stations consists of important equipment such as LNG storage tank , gas exchange equipment (Vaporizer) and pressure control equipment (Pressure regulator unit).
Liquefied natural gas station (LNG Station) and LNG storage tank will be under the supervision of DOEB: Department of Energy Business, Ministry of Energy. The engineering design, construction, installation, and safety must be strictly carried out under ministerial regulations and NFPA 59A.
Liquefied natural gas storage tank
LNG storage tank has its special function which stores liquid at very low temperatures -196 °C or LNG at -162 °C. The tank is designed by double-layered containers including inner containing LNG and outer vessels. Between Inner and Outer vessels, there is an annular space which is a vacuum working as an insulator. This vacuum layer is to protect heat transfer from outside. The tank is designed in both vertical and horizontal tank according to ASME SECTION VIII DIVISION1 as following.
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outer folding process
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inner tank with piping
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The welding of the outer and inner tanks
ASME SECTION VIII (PRESSURE VESSELS), Division 1
Division 1 provides requirements applicable to the design, fabrication, inspection, testing, and certification of pressure vessels operating at either internal or external pressures exceeding 15 Psig. Such vessels may fire or unfire. This pressure may obtain from an external source or by the application of heat from a direct or indirect source, or any combination thereof. Specific requirements apply to several classes of material used in pressure vessel construction, and to fabrication methods such as welding, forging, and brazing. Division 1 contains mandatory and non-mandatory appendices detailing supplementary design criteria, nondestructive examination, and inspection acceptance standards. Rules pertaining to the use of the single ASME certification mark with the U, UM and UV designators are also included
Application of LNG storage tank
1. Filling circuit
The cycle of filling LNG into the tank begins with LNG passing a check valve through a separate pipe into Top Filling valve and Bottom Filling valve. These valves control LNG flow to regulate the pressure during filling
1.1 LNG flows into the upper of LNG tank which has compressed gas (Compressed Gas). Therefore, LNG with a lower temperature combines with compressed gas. As a result, gas pressure in the top of tank is lower.
1.2 LNG also flows into the lower of LNG tank which is liquefied gas state. Therefore, the amount of added LNG to the tank and is constantly increasing. This will cause higher gas compression in the top of the tank.
To fill LNG and control the pressure efficiently , the amount of LNG flow must be controlled by on-off valve.
2. Pressure build-up coil
Using LNG consistently, the decreasing volume of the liquid lower the tank pressure. The principle of enhancing pressure depends on changing state of LNG from liquid to gas. With flowing through pressure build-up unit, the liquid will be changed to gas phase. Then, it returns to the upper tank to compensate lost pressure. Another important equipment is Regulator which controls on-off valve relying on the set pressure. When the tank pressure drops lower than the set point, the regulator will turn on the LNG flow. In contrast, the tank pressure increases higher than the set point, the regulator will narrow the LNG flow.
To sum up , the heat exchanger (Pressure Build-up coil) must be designed appropriately.
3. Pressure and Level Gauge
Monitoring tank pressure and volume are critical to its usage. Therefore, this device will have the principle as below
The mostly used pressure gauge is the Bourdon type to measure the pressure directly from the cylinder head which has different sizes and measurement ranges according to each type of tank and capacity.
Liquid level gauge mostly useห in differential pressure type which applies the pressure difference between two points to measure the level of LNG tank. One is from the upper of the tank. Also, the other is from the bottom of the tank. This pressure difference (Delta P) converts to be in units of height, such as millimeters of water (mmH2O) or Inch H2O to represent the height of the volume of LNG tank. In order to find the LNG quantity, there is a content chart to convert the height to weight.
4. Pressure Relief Valve
LNG can vaporize due to the heat. Although it is stored in the tank, it can vaporize as well, called as Normal Evaporation. Moreover, if the gas phase rises, the pressure will also gather. Unless it reduces pressure from other factors such as application or pressure release, the excessive pressure will reach to set point of the pressure safety valve. The safety valve will open to relieve the pressure to the set point.
This safety valve will calculate the relief rate properly for the tank and usually have 2 sets (1 set = 2 each) to switch operation and to calibrate.
5. Economizer
This process has a major device which is the Back-Pressure Regulator (BRP) or called Economizer. The economizer is set following the pressure outlet at the tank header. When the pressure reaches to the set point, the vapor will flow to liquefied gas circuit. Thus, the excessive pressure from economizer will be sent to customers instead of releasing out from the safety valve.
6. LNG supply circuit (Supply Circuit)
There are two types of LNG supply.
1. Direct liquid application which will pass through the on-off valve and flow directly to the next process, e.g. Vaporizer.
2. Applications connected to the Economizer system shall be applied for process that requires gas phase.
https://www.gmsthailand.com/product/lng-storage-tank-gms-interneer/ (https://www.gmsthailand.com/product/lng-storage-tank-gms-interneer/)
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What is Cogeneration Power Plant
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Cogeneration is the simultaneous production of two or more types of energy from a single fuel source. It is sometimes referred to as cogeneration, distributed generation, or recycled energy. In general, cogeneration power facilities are 50 to 70 percent more efficient than single-generation plants. Cogeneration is the utilization of otherwise wasted heat (such as the exhaust from a manufacturing facility) to deliver extra energy advantages, such as heat or electricity, to the building in which it is operating. Because recycling waste heat prevents the need of more destructive fossil fuels, cogeneration improves both the bottom line and the environment.
Even though combined heat and power (CHP) technology is sometimes referred to as cogeneration, there are important distinctions. Cogeneration is the process by which a simple cycle gas turbine generates electricity and steam, as well as steam utilized in other processes such as drying. The steam, however, is not utilized to power a steam turbine.
CHP combined-cycle power plants may generate both electricity and usable heat energy from a single source. Thermal energy (steam or hot water) gathered may be utilized to heat and cool as well as generate electricity for a range of industrial purposes. CHP is used by manufacturers, municipalities, commercial buildings, and institutions such as universities, hospitals, and military sites to cut energy costs, boost power dependability, and lower carbon emissions. Because it possesses the industry’s biggest gas turbine product range, GE is ideally positioned to provide its clients with the essential solutions to meet the requisite power-to-heat ratio for their CHP and cogeneration systems.
Process of Cogeneration
A cogeneration plant, like a CHP plant, generates both electricity and heat. Cogen technology, on the other hand, differs from CHP in that it generates energy using a simple cycle gas turbine. The exhaust energy from the gas turbine is then utilized to generate steam. Rather of being redirected to power a steam turbine as in CHP, the steam is completely used in other processes.
Power Plant with Combined Heat and Power (CHP)
A combined heat and power (CHP) power plant generates heat and electricity in a decentralized, energy-efficient manner. CHP plants may be constructed to power a single building or enterprise, or they can be designed to power an entire district or utility.
The main mover in CHP is powered by a fuel, which generates both electricity and heat. The heat is then utilized to bring the water to a boil and create steam. Some of the steam is utilized to power a process, while the rest powers a steam turbine, which generates further power. In a Cogen application, the steam is completely used in a process that generates no more electricity.
The Benefits of Combined Heat and Power
When compared to traditional energy generation, a CHP power plant may provide various benefits and advantages, including:
- Increased efficiency: CHP generates both electricity and heat while using less fuel than typical energy plants. It also collects heat and steam to create extra electricity, reducing the demand for fuel even more.
- Lower emissions: Because CHP systems use less fuel, they may reduce greenhouse gas emissions and other air pollutants.
- Lower running expenses: CHP’s efficiency lowers operating costs and may offer a hedge against rising energy prices.
- Dependability: Because CHP is a self-contained energy plant, it reduces dependence on the energy grid and may provide increased energy security and power generation dependability even in the event of a catastrophe or grid outage.
Large structures and infrastructures can benefit from CHP.
Intelligent combined heat and power production (CHP) makes a substantial contribution to energy generation for hospitals, airports, and other big buildings. CHP solutions not only help operators avoid large supply and distribution losses, but they also save 40% more fuel than separate generation and may help boost overall efficiency, profitability, and environmental responsibility.
The Benefits of Cogeneration
Cogeneration technologies, such as CHP, may provide greater savings and advantages than conventional power generation methods. Cogeneration, on the other hand, is inefficient compared to CHP since it does not employ steam to generate extra electricity.
- District heating: Cogeneration systems are used in district heating power plants to provide both energy and heating to local buildings and households. Unused steam is directed to provide extra energy when a CHP system is utilized for district heating.
- Industrial manufacturing: Industrial CHP plants enable enterprises that require a lot of energy to generate their own steady supply of electricity while increasing efficiency and lowering fuel use. CHP systems can power a wide range of industrial and manufacturing operations while also producing useful energy such as high-pressure steam, process heat, mechanical energy, or electricity.
- Institutions: Colleges and colleges, hospitals, jails, military bases, and other institutions rely on CHP facilities to satisfy their electrical and thermal energy requirements while enhancing power reliability. The CHP system has the potential to considerably reduce the costs and emissions associated with standard power generation methods.
- Municipal applications: Combined heat and power (CHP) is well-suited for municipal wastewater treatment facilities. Anaerobic digestion generates biogas in these facilities, which may be used to power onsite generators.
- Residential: CHP systems may be utilized to power energy-intensive multifamily buildings or to assist single-family houses in meeting their energy requirements.
When you have completed and commissioned your LNG Process and System and wish to run it commercially, you must register and obtain approval and a license to operate. The government entity in charge of these entry in the energy or oil and gas sector, particularly in Thailand, is known as the “Department of Energy Business” (DOEB).
https://www.gmsthailand.com/blog/what-is-cogeneration-power-plant/ (https://www.gmsthailand.com/blog/what-is-cogeneration-power-plant/)
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กองทุน GMS ช่วยเหลือชาวนาบ้านกลาง หมู่ 6 ทุ่งฝาย จังหวัดลำปาง ครั้งที่ 22
กองทุนGMS นี้ถูกจัดขึ้นตั้งแต่ปี 1 ตุลาคม ปี พ.ศ. 2553 เป็นแนวคิดของคุณสมเกียรติ ไชยศรีรัตนากูล ผู้ก่อตั้งบริษัท โดยนำเงินส่วนตัวมาช่วยเหลือชาวนาบ้านกลาง หมู่ 6 ต.ทุ่งฝาย จ.ลำปาง ในด้านการลงทุน เช่น การซื้อเมล็ดพันธุ์ข้าว ปุ๋ย หรือยาฆ่าแมลง ในนามบริษัท จี.เอ็ม.เอส ชาวบ้านจึงเรียกว่า “กองทุน จี.เอ็ม.เอส ” ทั้งนี้เพื่อช่วยเพิ่มผลผลิตเมล็ดข้าว และ ช่วงสร้างอนาคตที่ดีขึ้นให้กับชาวนา
โดยมอบหมายคณะกรรมการ กองทุนGMS รายชื่อ ดังต่อไปนี้ ช่วยดูแล
1. คุณจำนงค์ ธรรมวงศ์ (ผู้ช่วยผู้ใหญ่บ้าน)
2. คุณพรพันธ์ พัฒพร
3. คุณจงกลณี ณ ลำปาง
4. คุณสุภิญ อินต๊ะสงคะ
5. คุณกาญจนาวดี เลี่ยมสกุล
นอกจากนี้มีการกำหนดเงื่อนไขและระยะเวลาการยืมคืน เพื่อให้เกิดการหมุนเวียนกับชาวนารายอื่น และได้รับโอกาสเช่นเดียวกัน
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Water Treatment in Oil & Gas Business
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Reservoirs, according to many outside the oil and gas industry, are huge subterranean hydrocarbon lakes. In reality, hydrocarbons are found in porous layers of rock that are covered by impermeable rock or shale. Sandstone and limestone are the most common oil-bearing rocks. The pores in these rocks range in size from sub-micron to tens of microns. This enables fluids to pass through the rocks.
The water beneath the oil is also known as “connate” or “formation” water. Their origins differ. Connate water is water that was caught in rock during formation and whose composition can change over time. Under the impermeable cap rock, formation water is trapped with the hydrocarbons. When an oil well is dug, it produces oil, gas, and water all at the same time
Oil Separation
When reservoir fluids (gas, oil, and water) are brought to the surface for separation and treatment, the pressure drops, resulting in the formation of insoluble scales. In basic language, decreased pressure causes soluble bicarbonates to form carbonate ions,
- releasing CO2 gas: 2HCO3− → CO32− + CO2↑ + H2O
When coupled with calcium ions, the carbonate ion produces insoluble carbonate scales. This can result in reduced flowrates (loss of money) as well as a loss of system integrity. To avoid scale formation, reservoir fluids can be dosed with a scale inhibitor chemical while still under high pressure. The first stage of oil separation is typically a horizontal three-phase separator sized to optimize oil and water residence times. It is critical to handle the removal and disposal of solids generated by the use of oil, gas, and water. All gas/oil/water/solid separation in these units is governed by Stokes’ Law.'
It is, in truth, far from clean. It will contain particles as well as residual oil in the form of small droplets distributed in water. Water will include certain dissolved hydrocarbons and gases, such as (corrosive) carbon dioxide and lighter hydrocarbons, as well as water-soluble chemicals required to enhance hydrocarbon production. Water from onshore and offshore oil and gas production systems is discharged into local river courses, estuaries or near-coastal waterways, or the sea from offshore oil and gas production platforms. The presence of potential toxins in these streams must be addressed in order to protect the ecology. A little number of hydrocarbons in the water may be recovered and reintroduced into the main production system
Wastewater de-oiling
Mineral therapy was used in the early stages of treatment, which eliminated larger oil droplets but not small ones. For removing dispersed oil droplets from produced water, the following methods have been developed:
- increasing the overall droplet size (coalescence)
- systems which change the specific gravity of the oil droplet by attaching to it a bubble of gas
- techniques that apply increased gravitational forces to the separation process, for example, hydro cyclones and centrifuges
These advances in reducing residual hydrocarbons in produced waters enable dispersed oil in water (OIW) concentrations as low as 40 mg/l. Initially, this was sufficient to meet the discharge standards of the UK regulatory agency. A new regulation mandates offshore businesses to reduce the number of hydrocarbons leaked overboard on an annual basis.
This amount of oil should be 15% less than the total tonnage delivered by the individual assets in 2001. Any quantity of hydrocarbon released in excess of the permitted level is subject to a fine of £108 per kilogram. These calculations do not take into account new fields or the fact that water production grows with time.
Currently, the maximum OIW value in produced waters is 30mg/l. As a result, some operators must treat generated water to significantly higher standards than previously, while others have set a zero produced water discharge goal for both existing and new assets. The competent environmental protection agency regulates onshore discharges, which may include maximum limitations for heavy metals and dissolved hydrocarbons
Other waters
Two more processes occur while the oil is produced. As the gas cap expands, so does the oil/water contact. The first mechanism is unfavorable because it permits dissolved gas in oil to leave solution. Gas is more mobile than oil and will gravitate toward producing wells.
This is undesirable since it means that oil is bypassed and remains in the reservoir. When the oil/water contact is increased, more water is created along with the oil. This decreases oil income while increasing the amount of water that must be treated before it can be discharged
How can these approaches be avoided, or at the very least delayed, until the field’s revenue is maximized? The advantages of allowing water to flow into oilfields were discovered by chance as early as the early American oilfields. Water used to infiltrate oil-bearing strata by mistake and flush the oil towards the producing wells. Since then, knowledge has expanded significantly, and water injection is now employed in nearly all new oilfields.
The injected water has two purposes: it maintains reservoir pressure high enough so that gas cannot leave solution, and it creates an immiscible flood front that drives oil towards the wells. Regardless of the approach used, the total volume of oil recovered will increase dramatically. According to World Oil, a successful water injection operation may increase overall hydrocarbon recovery by 40%.
- Seawater (if the asset is offshore or near the coast with a few exceptions)
- Produced Waters (see above)
- Aquifer waters (if easily accessible)
- River or estuarine waters
- Domestic and/or industrial waste waters
The Saudi Aramco Qurayyah system purifies 7 million barrels of seawater per day (1.1 million m3/day) before pumping it 350-400 kilometers inland for injection into the Ghawar oilfield. Since 1978, the plant’s capacity has been increased, and it now serves the Khurais oilfield. Before they can be safely injected into a hydrocarbon-bearing deposit, all of them must be treated
Injection Water Use
The current issue of injection water treatment will concentrate on saltwater, which is the most commonly used injection water. Seawater contains suspended particles, bacteria, and dissolved oxygen, all of which may wreak havoc on the reservoir’s ability to store water for extended periods of time, as well as the materials used to manage the water. Pipelines, injection wells, and any metals used beneath the ground to transport water to the reservoir are examples. Because saltwater may be used for cooling, it must first meet the cooling quality standards. This includes the removal of pathogens, marine life, and the treatment of larger suspended particles.
This is accomplished by injecting broad-spectrum bactericides, mostly chlorine in the form of sodium hypochlorite, into the water supply pumps. This is typically produced via seawater electrolysis. The larger suspended particles, such as hard–shelled marine animals and plankton, are next removed via coarse filtration. These filters remove a variety of particles depending on how the water is used. The typical range for solid removal is 80m to 6.4mm. After cooling, water injected into a hydrocarbon-bearing deposit may require further filtration.
There are now two schools of thought on this topic: one advocate’s filtration to avoid reservoir pore obstruction, while the other claims that cold seawater entering hot rock will produce rock fissures, allowing water (and particles) to flow freely. A bank of high-rate dual media downflow filters is often used for secondary filtering. After eliminating the sediments and most bacteria, the dissolved oxygen must be treated.
Because carbon steel is preferred for handling the high pressures required to inject water into the formation, the dissolved oxygen must be removed. This oxygen is removed from the seawater using vacuum deaeration, which entails a vertical tank with many vacuum stages.
The remaining dissolved oxygen is removed using a scavenger chemical based on sulphite : SO32− + O2 → SO42−
The first stage vacuum is typically provided by liquid ring vacuum pumps, with lower vacuums provided by air/gas ejectors. In most cases, the pump seal/cooling water is cold filtered seawater. The conditioned saltwater is then pushed under high pressure to the water injection wells. The switch from aerobic to anaerobic conditions downstream of the deaerator can allow some anaerobic microorganisms to grow, notably sulphate reduction bacteria, potentially jeopardizing the integrity of any carbon steel systems Microbiologically influenced corrosion is often mitigated by intermittent use of organic, non-oxidizing biocides (MIC). No corrosive properties like chlorine. Aldehydes, quaternary ammonium compounds, and various kinds of quaternary phosphonium compounds are dosed alone or in combination as single or mixed chemical biocides. Organic biocides are expensive and are typically dosed once a week for 1-2 hours at 1,000 mg/l.
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Steel Pipe in Oil & Gas Business
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The Oil and Gas industry is undoubtedly the world’s largest in terms of financial worth. Oil and gas companies frequently contribute considerably to national GDP and employ millions of people worldwide. The most common products in the oil and gas business are fuel oil and gasoline (petrol).
The three major areas are upstream, midstream, and downstream.
- Upstream refers to the search for underwater and subterranean natural gas and oil resources, as well as exploratory well drilling.
- Midstream refers to the transportation, storage, and processing of oil and gas.
- The downstream market consists of the filtering of raw materials collected during the upstream phase. It is concerned with the refining of crude oil and the purification of natural gas
Conditions that are demanding
The oil and gas industry are well-known for working in tough environments with potentially hazardous substances. As a result, special metal grades have been developed to withstand corrosion and extreme temperatures. As the oil and gas sector hunts for new hazardous locations, demand for corrosive resistant duplex steel products rises. With increasing depth of offshore oil exploration, the pressure on duplex and super duplex stainless steel pipes deployed in hostile corrosive environments grows
Stainless steel applications and advantages
Super duplex steel is used by oil and gas firms for a variety of reasons, including:
- Excellent corrosion resistance, including pitting and intergranular corrosion.
- Greater tensile and yield strength • Excellent weldability
As a result, Super Duplex Stainless Steel may be found in pipe systems, separators, scrubbers, and pumps, as well as manifolds, heat exchangers, and flowlines. Stainless steel is employed in a wide range of nautical applications, including offshore oil rigs. Because crude oil is corrosive, stainless steel is perfect for storing it as well as for subsea applications such as deep-sea drilling, where equipment must be extremely durable and corrosion resistant.
Duplex 2205 (22 percent chromium, 5 percent nickel) and 2507 (25 percent chromium, 7 percent nickel) pipes, as well as Super Duplex 2507, are used in the offshore oil and gas sector for corrosion resistance. Duplex steel is also resistant to chloride-induced stress corrosion cracking and can tolerate high pressures. Petro Canada selected Super Duplex 2507 and Duplex 2205 pipes for its Newfoundland oil field because they can withstand high salt concentrations without corroding, have high tensile strength, excellent pitting, cracking, and impact resistance, little thermal expansion, and good conductivity. Stainless steel is a long-lasting material that may be used to properly store oil and gas production fluids. Stainless steel offers a great life cycle environmental and economic performance
Nickel Alloy and Inconel in Oil and Gas
Nickel alloy and Inconel, together with stainless steel, are two of the most durable and flexible materials used in the oil and gas industry. Inconel is commonly used in high-performance equipment that must be reliable in harsh environments. Chemical processing and pressure vessels, well pump motor shafts, steam generators, turbine blades, seals, and combustors all use it.
Petroleum and natural gas Materials for Special Piping
Special Piping Materials has been involved with the oil and gas industry since its inception. We collaborate with the top mills and manufacturers in the world to best serve our clients, many of whom are industry leaders and innovators. We will continue to find and supply the best grade super duplex stainless steel and Nickel Alloy items – pipes, flanges, and specialized fittings. Some people mix up a metal tube with a metal pipe, but those of us in the oil and gas industry know better In brief, tubing is used for structural purposes rather from pipe, which is used for liquid transmission. The wall thickness (as determined by the pipe’s outer diameter) is crucial in tubing. Pipe size and walk thickness are key criteria to understand according to the American National Standards Institute (ANSI)
Pipe Fundamentals
Steel pipes are used by oil and gas industries to transport gas and liquids. SplashTRON® coating is widely requested by our clients for oil, gas, and propane pipelines. Tubing is usually more expensive than carbon or low alloy steel pipes. The internal diameter of the pipe influences how much product can flow through it. Yield strength and ductility are critical properties.
Tubing Fundamentals Tubes are used to transport fluids but are also used as conveyor belt rollers, bearing casings, and concrete piling casings. In well construction, tubing refers to casing and tubing strings. Tolerances for tubes include their diameter, wall thickness, straightness, and roundness. Tubes must fulfill stringent specifications and be tested on a regular basis for hardness and tensile strength. Exact outside diameters disclose the weight-bearing capabilities of the tube.
Steel tubes with tiny outer diameters (up to 5 inches) and large lengths are used in pressure devices. Mild steel, aluminum, brass, copper, chrome, or stainless steel are all acceptable materials. Inevitably, the material used has an influence on the final user
Tubes and Pipes
There are two sorts of sizing systems:
- The inside diameter (ID) of a cylinder is measured in inches. In Europe, the metric equivalent is DN, which stands for “diameter nominel.” The thickness of the wall is measured by the schedule. The number is not a unit of measurement.
- The schedule number denotes the thickness of the pipe wall. The same schedule number might appear on pipes with different wall thicknesses. Because the NPS is accounted for in the thickness. If two pipes have the same NPS but different schedule numbers, their IDs will vary but their ODs will remain the same. A conversion chart can assist in demonstrating the relationship between pipe size, schedules, and wall thicknesses
Seamless, ERW, and LSAW pipes
Seamless, ERW, and LSAW pipes are utilized in the oil and gas industry. These pipes are available in a range of materials and grades. Without welding, a seamless pipe is produced from a hard steel billet on a shrill rod. Welded pipes are created by cutting, bending, and then welding coils or plates.
Seamless pipes do not have seam welds. To make tubular sections, steel billets are heated and bored. In the oil and gas industry, seamless pipes are used to transport and distribute fluids such as oil, gas, slurries, steam, and acids. Also used in oil and gas refineries to refine oil and gas. In ordinary plumbing applications, seamless pipes can be employed.
- ASTM A106, A333, A53, and API 5L Carbon Steel Seamless Pipes
- ASTM A335 seamless ASTM A335 P5 to P91 chrome-moly alloy steel pipes for high temperature and pressure applications.
- ASTM A312 stainless steel seamless pipes in 304, 316, 321, and 347 sizes.
- ASTM A790/A928 double ferritic and austenitic duplex and super duplex seamless pipes.
- Seamless pipes are offered in Inconel, Hastelloy, Cupronickel, Monel, and Nickel
ERW piping (Electric Resistance Welding)
ERW pipes are made from steel coils. These pipes are constructed using coils that have been uncoiled, polished, cut, and electronically aligned into the pipe shape. The diameters of these pipes range from 1/2 to 20 inches. Carbon steel (ASTM A53) and stainless steel ERW pipes are offered (ASTM A312). ASME B36.10 and B36.19 are the basic guidelines for these Pipes. In terms of pricing and performance, ERW Pipes are an excellent alternative to Seamless Pipes.
Pipes made of LSAW (Longitudinal Submerged Arc Welding)
Welding via submerged arc LSAW tubing Steel plates is cut, bent, and welded together. LSAW pipes come in bigger diameters than traditional pipes. These pipes range in size from 16 to 24 inches, although they may be utilized for pipelines up to 48 inches in length. LSAW pipes are classified into two categories. Spiral types include HSAW, SSAW, and SAWL. Both the interior and exterior of DSAW pipes have a junction weld. However, LSAW pipes have just one seam weld on the pipe cover. 5L large-diameter LSAW pipes are frequently used to carry hydrocarbons across vast distances. Spiral weld pipes (HSAW or SSAW) are rarely used in the oil and gas industry
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Offshore Oil and Gas
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The extraction of offshore oil and gas is critical to the world’s energy supply. It will necessitate increasingly sophisticated technology as well as increased environmental consciousness. Offshore production accounts for 30% of global oil output and 27% of global gas production. Despite considerable onshore development of unconventional resources such as oil sands and shale oil and gas, these percentages have been stable since the early 2000s. Offshore production now accounts for 20% of world oil reserves and 30% of global gas reserves
Cost and time constraints
Offshore production, like unconventional resources, is restricted by cost and the environment. Despite technological advances, each stage of oil and gas production, from discovery to drilling to extraction to platform and vessel construction, requires billions of dollars in investment. Each project’s cost-competitiveness must be assessed independently. In response to environmental events like as the Macondo blowout in April 2010, companies are updating existing facilities, adjusting seabed installation designs, and strengthening best practices. Constant vigilance is required, especially while operating in such hazardous environments as the Arctic.
Deep-water output is increasing
Offshore production in 200-meter-deep oceans began in the 1950s. On the seafloor, platforms with metal or concrete legs were constructed. Following the 1973 oil crisis, North Sea output increased dramatically. Half of today’s 17,000 platforms are permanently anchored to the bottom. Firms began pushing deeper in the 1990s, between 400 and 1500 meters (deep-water) (ultra-deep water). Companies are currently producing oil at depths of up to 3,000 meters and want to reach 4,000 meters. To reach such depths, hundreds of meters of silt must be excavated through.
Offshore deep-water production is on the rise. The Libra offshore oil field development, for example, is located more than 200 kilometers south of Rio de Janeiro and seeks deposits 3,500 meters beneath a salt layer, which is 2,000 meters below the seabed. Deep-water production has increased from 3% in 2008 to 6% now
Deep-water production has certain disadvantages
Instead of fixed platforms, deep-water production needs floating platforms connected to wellheads via flexible risers. Some risers transport water and gas to producing wells, while others transport oil to the surface. The risers are insulated to prevent the oil, which is extracted at temperatures exceeding 50°C, from cooling too quickly and clogging the pipes at deep-water conditions. Submarine stations are transforming into a sort of undersea factory, doing duties such as oil and gas separation.
Pipelines can be laid by sophisticated boats and underwater robots to bring the oil onshore. If the oil field is more than 1,000 meters deep and too distant from the shore, the oil is produced, stored, and dumped using a barge or tanker. These FPSOs have a capacity of up to 2.5 million barrels of oil. A field may have many FPSOs, each of which can last 20–25 years. FLNG (floating liquefied natural gas) facilities are also being studied, which would allow for fast liquefaction of gas after production. There is no need for costly onshore gas pipelines and liquefaction plants, which frequently spark debate due to their environmental effects.
Offshore Exploration
First and first, offshore oil and gas must be located. Soundwaves are used by companies such as Geophysical Surveys to examine the seafloor. The energy source in water is a series of compressed air-filled air-chambers of various diameters. The source emits high-pressure energy bursts into the water. The returning sound waves are detected and recorded by hydrophones deployed along cables. Strict mitigation measures are used throughout the procedure to safeguard marine mammals and other marine animals. Geophysical surveys are commonly used for oil and gas exploration, but they are also used to find sand and gravel for coastal restoration.
Drilling in the Ocean
Once a promising resource has been located, firms will use MODUs to drill highly controlled exploration wells (MODUs). Some MODUs is converted into production rigs, which collect oil rather than drilling for it. The oil firm usually replaces the MODU with a permanent oil producing rig. MODUs is classified into four types
- A SUBMARINE OR BARGE MODU is a barge that sits on the seafloor at a depth of 30 to 35 feet (9.1 to 10.7 meters). On the deck of the barge, steel pillars rise above the waterline. A drilling platform is supported by the steel pillars.
- A jackup is a rig that floats on top of a barge. The ship tows the barge to the drill site. Once put up, the jackup’s legs may be extended to the seabed. The legs are weighted so that they do not contact the ground. The jackup will continue to ratchet the legs until the platform is elevated above the water. This shields the rig from the effects of tides and waves. Jackups can work at depths of up to 525 feet (160 meters)
- A drilling rig is located on the top deck of a drill ship. The drill goes all the way through the hull.
- Drill ships use anchors and propellers to control drift while drilling for oil.
- Semisubmersibles float on the ocean’s surface on massive, submerged pontoons. Others necessitate the use of a second vessel to transport them to the drilling To hold the structure upright, most use up to a dozen anchors. Some can convert from drilling rigs to production rigs, reducing the need for a second rig if oil is discovered.
MODUs drill into the ocean floor to locate oil and gas resources. The riser is the part of the drill that travels beneath the deck and into the water. The riser is the piece that links the floor to the rig. Engineers insert a drill string, which is a group of pipes, through the riser. The blowout preventer is currently at sea (BOP). By hydraulically sealing the pipe leading up to the rig, an emergency blowout can be avoided. The BOP is one of several interconnected levels of offshore energy safety precautions.
Engineers use metal casings, similar to those used on land-based oil rigs, to support the well. Casings keep the well from collapsing. The walls of each casing are made of cement. Thinner casings are used in deeper wells. Drill bits become smaller as the depth of a hole increases. A liner hanger O-ring is used by engineers to seal each annulus where a thinner casing joins a larger one When the MODU encounters oil, engineers must plug the well. Two plugs will be used to plug the well bore by the engineers. Near the oil deposit. Drilling mud or seawater holds the plug-in place while engineers insert a top plug to cap the hole. A production rig may then take over.
Offshore Production
Once a commercially viable well is found, and the limits are met, the focus shifts from exploration to production. Drilling in ultra-deep water at high temperatures and pressures is an offshore oil and gas industry marvel. Every offshore environment appears to have its own manufacturing platform. The permanent platform may be constructed at depths of up to 1500 feet in the sea.
- For drilling and production activities, the Compliant Tower (CT) is a thin, flexible tower supported by a piled foundation. Unlike the fixed platform, the compliant tower can withstand significant lateral loads and is used at sea depths ranging from 1,000 to 2,000 feet.
- The Tension Leg Platform (TLP) is a floating structure that is fastened to the bottom by piles. Ankle tendons provide a broad variety of water depths while allowing for little vertical mobility. Larger TLPs have been successfully deployed at sea depths of 4,000 feet.
- A floating mini-tension leg platform (Mini-TLP) was created to generate smaller deep-water reserves that would be uneconomical to extract using more traditional deep-water production technology. For larger deep-water discoveries, a utility, satellite, or early-production platform. In 1998, the world’s first Mini-TLP was installed.
- The SPAR Platform (SPAR) is a large diameter vertical cylinder with an attached deck.
- The hull is moored by a taut catenary system of six to twenty lines anchored into the bottom. SPARs are now used at water depths of up to 3,000 feet, but current technology allows them to be used in depths of up to 7,500 feet.
- A Floating Production System is a semi-submersible unit containing drilling and production equipment (FPS). It’s held together with wire rope and chain and pushed about by spinning thrusters. Subsea well output is transferred to the surface deck through production risers designed to handle platform motion. The FPS might be rather high.
It might be a single subsea well supplying a neighboring platform, FPS, or TLP, or it could be a network of wells supplying a distant production facility via a manifold and pipeline system. Now used in marine depths of up to 5,000 feet
The FPSO is a large tanker that is permanently attached to the bottom. On an FPSO, oil generated from a neighboring subsea well is offloaded on a regular basis onto a smaller shuttle ship. The oil is subsequently transferred to an onshore processing plant by the shuttle tanker. An FPSO may be appropriate for marginal resources in remote deep-water sites without pipeline infrastructure.
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Onshore Oil and Gas
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Onshore work is associated with buildings/structures constructed on land near the coast for oil and gas exploration and extraction. Refineries and boreholes are examples of onshore operations
Large crude oil tanks for pre-processing storage may be found at onshore oil terminals. Tankers deliver oil to these tanks, which serve as buffers. The rate of oil tanker supply exceeds the plant’s processing capacity. Even if the export route is unavailable, offshore manufacturing can continueTo heat the oil prior to separation, onshore oil terminals use fired heaters. They stabilize the oil, remove sediments and produced water, and allow light hydrocarbons to flash off. Large separation vessels allow the oil to stay in the vessel for an extended period of time, allowing it to effectively separate. To maximize vapor emission, onshore separators operate at near-atmospheric pressure. The oil processing factory works hard to meet the vapor pressure requirements of the oil. Use as a fuel gas or export it. Stabilized oil is transferred to storage tanks before being tankered overseas or to a local refinery for processing.
Liquid removal equipment may be found in onshore gas terminals. NGL, produced water, and glycol are examples of liquids (MEG or TEG). Liquid and gas are separated by slug catchers, which are either a network of pipelines or a huge cylindrical jar. To condition the gas, many treatment techniques are applied. Such operations include pre-user gas compression, glycol dehydration, and gas sweetening Because they may be positioned in the heart of a forest, a mountain top, a desert, or even a city or hamlet, onshore refineries are simpler to reach than offshore refineries. Onshore well drilling equipment is more easily available than offshore well drilling equipment. Because of significant land exploration and exploitation, the chances of discovering fresh oil and gas deposits on land are lower than in the waters
Furthermore, offshore oil and gas exploration presents more challenges than onshore exploration. Onshore refinery construction projects must consider ground strength and wind loads, whereas at sea, other factors such as currents and ocean waves must be considered. Refining necessitates the use of more complex human resources and expertise Offshore exploration also has higher operational costs than onshore exploration. The selection of structural materials for offshore projects cannot be left to chance. Consideration must be given to marine environmental factors such as corrosion and biota growth failure. An offshore rig has the advantage of being mobile because it extracts oil and gas from previous locations using floating platforms such as FPSOs and TLPs.
Drilling rigs, associated equipment such as casing and tubing, large amounts of water, and drilling muds are used in the development of hydrocarbon reservoirs. Oil and gas are either naturally pushed to the surface (if the reservoir has enough pressure) or artificially pushed to the surface (using a pump or other mechanism). The surface is the barrier that separates oil, gas, and water. Sour crude oil is crude oil containing more than 30 mg/m3 hydrogen sulfide. The crude oil may require additional processing, such as gas removal. The crude oil produced is piped or shipped to refineries.
The vast majority of natural gas is methane, with only trace amounts of other hydrocarbons. Gas well condensate may need to be processed. Common separation methods include pressure reduction, gravity separation, and emulsion “breaking.” The gas produced can be used as a fuel or as a feedstock in the production of petrochemicals. Mercaptans and hydrogen sulfide may also be present. Amine scrubbing is a method of sweetening sour gas.
Drilling waste fluids, drilling waste solids, produced water, and volatile organic compounds are all produced during onshore oil and gas production. Drilling waste muds are classified into several types. Oil invert mud systems may contain up to 50% diesel oil. Drilling wastes may include, in addition to drilling muds (bentonite), additives (polymers, oxygen scavengers, biocides, and surfactants), lubricants, diesel oil, emulsifying agents, and other drilling-related wastes. Drill cuttings, flocculated bentonite, weighting materials, and other additives are all found in drilling waste solids. Used oils, cementing chemicals, and organic compounds are among the drilling wastes During crude oil field processing, heavy hydrocarbon residues and polynuclear aromatic hydrocarbons (PAH) are created (PAHs). There is also contaminated dirt, used oil, and discarded solvents
The majority of wastewaters include suspended particles. A biocide or hydrogen sulfide scavenger (such as sodium hypochlorite) is frequently employed before reinjecting or disposing of sour water. Pigging operations clean crude pipelines on a regular basis, resulting in spills and heavy metal sludge buildup. Backfill is a non-toxic solid waste product.
Onshore oil and gas, as well as geothermal energy
- Drilling underground deposits is required for onshore oil and geothermal energy extraction. Prospecting refers to the systematic search for oil, gas, and geothermal deposits. Onshore oil and gas extraction is simpler and less expensive than offshore extraction. Seismic reflection is a technique used in the exploration of oil, gas, and geothermal deposits. In Germany, mature onshore fields with a large maximum extraction volume and a long extraction phase are frequently used for crude oil extraction.
Conventional Oil Extraction onshore
- There are three levels of difficulty in conventional extraction: primary, secondary, and tertiary.
Unconventional Oil Extraction onshore
- As conventional oil reserves dwindle, crude oil is being extracted from unconventional deposits such as oil sands or oil shale
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Subsea Oil and Gas
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Petroleum is a fossil fuel that includes all liquid, gaseous, and solid hydrocarbons. Petroleum is discovered in the Earth’s crust in porous rock formations. Huge amounts of oil and gas have been extracted in recent years from “tight” rock formations such as shale. The world’s second largest oil reservoir is the Athabasca tar sands in Alberta, Canada. Oil has become the world’s primary energy source due to its high energy density, ease of transport, and relative availability. Petroleum is also utilized in the production of pharmaceuticals, solvents, fertilizers, pesticides, and polymers.
Petroleum has been in use since prehistoric times. Babylon’s walls and towers were built with asphalt extracted from oil mines along the banks of the Issus River, a tributary of the Euphrates. In ancient Persia, petroleum was also used for medicine and illumination. Bamboo-drilled wells were producing oil in China by 347 AD.
Abraham Gessner of Nova Scotia, Canada, devised a method to produce kerosene from coal in 1846. The first large refinery was created in Ploesti, Romania, in 1856, using indigenous oil. Edwin Drake’s Titusville, Pennsylvania, well in 1859 is commonly considered as the first modern oil well. Drake’s well was drilled rather than dug, was driven by a steam engine, and was sponsored by a company, and it resulted in the first substantial oil boom. From then on, “rock oil” began to supersede whale oil as the primary source of light fuel. In the 1800s, liquefied petroleum gas (LPG) was developed. In the early twentieth century, the internal combustion engine and its development into cars created a need for gasoline. This accelerated the industry’s expansion.
The widespread use of natural gas as a fuel is novel. Crude oil is produced by an oil well. However, dissolved gas is released when crude oil is brought to the surface and exposed to reduced pressure. Due to its lower density, a “cap” of natural gas may float above the oil depending on the reservoir. Historically, there was less gas infrastructure, and gas was considered an annoyance. What couldn’t be used to power machinery was either buried or flared off (burned). Natural gas has become an important source of heating and electricity generation due to its extensive infrastructure.
Oil and gas account for more than 60% of total energy consumption in the United States, with oil used for transportation and gas used for electricity generation. Oil and gas, like all fossil fuels, are nonrenewable energy sources with finite supplies, according to experts. However, technology has always played an important role in oil and gas exploration. Supply and demand determine oil and gas prices, and as prices rise, so do technological innovations. This has enabled the United States and the rest of the world to constantly seek out and exploit new sources of oil and gas to replenish those that have been depleted over time.
There are numerous inland and offshore oil and gas fields around the world, and the term subsea refers to the exploration, drilling, and development of these fields. Underwater oil fields and infrastructure are referred to as subsea wells, subsea fields, subsea projects, and subsea developments.
There are two types of subsea oil field development: shallow water and deep water. When bottom-based facilities such as jack up drilling rigs and permanent offshore structures are used, saturation diving is possible at shallow water depths. Deepwater refers to offshore operations that necessitate the use of floating drilling boats and floating oil platforms, as well as remotely operated underwater vehicles (ROVs), because human diving is impractical.
The first subsea completion took place in Lake Erie in 1943, in 35 feet (11 meters) of water. Diver intervention was necessary for the installation, maintenance, and flow line connections of a land-type Christmas tree. In 1961, Shell drilled their first subsea well.
They were intended for use at depths of up to a few hundred meters. In the intervening years, technology has advanced to allow for deep-water production, and the industry is constantly expanding its reach through the use of fixed platforms, compliant towers, SPAR (single point anchor reservoir), and FPSOs (Floating Production Storage Offloading).
A subsea development is an oil or gas field that is located on the seafloor. Semi-submersible mobile drilling rigs are used to drill wells from the water’s surface. A “wet tree” is then used to seal the wells on the seafloor. Most subsea systems use underwater flowlines to transport production to a surface processing system. A simple subsea system consists of a single well that feeds a nearby platform. Multiple wells flow through a subsea manifold and then to a production plant, which could be offshore or onshore. Figure 1 displays a number of subsea production components that are coupled to floating facilities.
Total field development expenses are reduced because an existing platform may be used for production or a dedicated platform can be located in shallower water.
The first underwater completion occurred in Lake Erie in 1943, at a depth of 35 feet. In 1961, Shell built the first subsea well off the coast of California. Companies focused on fixed platform technology with dry trees after initially showing interest in California and the Gulf of Mexico. During that time, Norway advanced subsea technology, beginning with the 1982 Frigg field in the North Sea and continuing for decades. Oil companies, particularly Shell USA and Petrobras Brazil, continued to develop subsea systems for deep-water applications. Shell’s Mensa field in the US Gulf of Mexico began producing in 5,376 feet of water in July 1997, breaking the previous record. Shell’s Tobago project in the Gulf of Mexico is the deepest subsea development at the moment.
Operators are now placing processing equipment on the seafloor thanks to advancements in subsea technology. Gas-liquid separation, electrical submersible pumps, and sand management are examples of technologies. The development of process technology is centered on oil-water separation and subsea produced water disposal. To extract offshore reserves, topside equipment (pump, separator, water handling, compressors, processing, and storage) is used. Surface facilities are expensive, and space in deep or remote waters is limited, making production difficult.
Production risers, flow lines, and associated production control systems comprise the subsea production system. A subsea production system manages fluid production and transportation, enabling for the exploitation of remote and/or deep-water deposits by installing wellheads and associated mechanical and electrical equipment on the seafloor.
Surface or shore infrastructure can be linked to subsea wells. Modularized subsea technology can improve recovery factors by lowering well backpressures while also cutting development and production expenses (e.g. via multiphase pumping or subsea separation). Subsea technology is gaining traction in West Africa, Brazil, and Asia.
The oil industry has been able to develop reserves in greener areas and water depths down to over 3000 meters by moving from dry land to shallow-water areas via wellhead platforms, and then into deeper water depths of a few hundred meters. Improved subsea solutions, such as better drilling equipment, installation technologies, and control systems, are required to meet increasing criteria. As new technologies enable the design and installation of more advanced subsea systems, the subsea industry is undergoing a transformation. Subsea processing units, for example, can use pumps or compressors to separate different fluid phases and boost the fluids (subsea factory).
Small fields are linked to bigger facilities and field centers by subsea plants. Subsea technology extends the life of existing platforms and infrastructure, allowing for greater extraction of resources from the field. Advances in subsea technology allow for development in ultra-deep seas. Subsea plants can be linked to onshore processing facilities in no-frills areas. Production can be managed on the ground or through linked-in installations. Extreme weather rarely has an impact on the amenities.
Subsea technology enables more environmentally friendly offshore development and operations. Reduced ship and helicopter traffic during operations lowers emissions, while remotely controlled technology lowers high-risk activities
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Designs for Cryogenic Tanks
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Liquid-storage vessels
Liquid hydrogen (LH2) is typically stored in cylindrical tanks. Spherical tanks can carry a significant amount of liquid. Cryogenic tanks are vacuum insulated to minimize evaporation losses and contain redundant pressure release mechanisms to prevent over-pressurization. Liquid hydrogen tanks typically operate at pressures of up to 850 kPa (123 psi).
The pressure release system will function at a maximum pressure of 1,035 kPa (150 psi) in most tanks. Even if hydrogen is not drawn from the tank, LH2 evaporation will occur, and the resulting pressure will be released on a regular basis by the pressure relief mechanism as part of normal operation.
Cryogenic tanks are constructed and manufactured in accordance with well-established norms such as:
- The US Department of Transportation’s restrictions apply to transportable storage tanks.
- Transport Canada imposes limitations on mobile storage tanks.
- Regulations such as the ASME Boiler and Pressure Vessel Code (BPVC) apply to stationary storage tanks.
- Larger tanks are occasionally designed in line with standards such as API Standard 620, Design and Construction of Large, Welded, Low-Pressure Storage Tanks.
- Stationary tank supports should be able to resist fire exposure without failing.
The paperwork for each vessel should include a description of the vessel, a list of available drawings or other materials, the most recent inspection results, and the name of the responsible person. Vessels must also be marked in accordance with the applicable regulations. Each cryogenic liquid storage tank (stationary and mobile) should be legibly labeled “LIQUEFIED HYDROGEN – FLAMMABLE GAS.”
A warning labeled “Do not spray water on or into the vent hole” should be displayed on the vessel near the pressure-relief valve vent stack. Local first responders and firefighters should be specially trained in LH2 spill response tactics.
Cryogenic liquids and the containers in which they are stored
Cryogenic tanks are used to safeguard cryogenic liquids. Cryogenic liquids are liquefied gases that have temperatures of -150 °C or below. Byproducts include oxygen, argon, nitrogen, hydrogen, and helium. Cryogenic tanks may also be used to store gases at higher temperatures, such as LNG, carbon dioxide, and nitrous oxide. These are components of gas supply systems used in a number of sectors including metal processing, medical technology, electronics, water treatment, energy generation, and food processing. Low temperature chilling uses using cryogenic liquids include engineering shrink fitting, food freezing, and bio-sample storage.
Cryogenic tanks are thermally insulated and are typically equipped with a vacuum jacket. They are created and manufactured to stringent standards in compliance with international design criteria. They might be fixed, movable, or transportable.
Static cryogenic tanks are designed for permanent usage; however, transportable small tanks on wheels for use in workshops and laboratories are provided. Because static cryogenic tanks are typically classified as pressure vessels, new tanks and their associated systems will be built and installed in accordance with the Pressure Equipment (Safety) Regulations. For applications requiring direct access to the liquid, non-pressurized open neck vessels (Dewar flasks) are also available. The tanks are available in a range of sizes, pressures, and flow rates to meet the different demands of the customers. Tanks used to transport cryogenic liquids must comply with the Regulations on the Carriage of Dangerous Goods and the Use of Transportable Pressure Equipment.
Use, operation, maintenance, and disposal of cryogenic tanks
All applicable regulations, such as the Pressure Systems Safety Regulations for static tanks and the Carriage of Dangerous Goods and Use of Transportable Pressure Equipment Regulations for transportable tanks, must be followed when operating and maintaining cryogenic tanks. Cryogenic tanks must be maintained and operated by trained personnel.
The Regulations require cryogenic tanks to be inspected on a regular basis, as well as routinely maintained and subjected to formal examinations on a periodic basis for static tanks. To ensure that the tank is in safe operating condition between official examination times, an inspection and maintenance program should be created. This will include a Written Plan of Examination, which will be created by a competent person(s), as well as periodic formal examinations conducted in accordance with the scheme.
Transportable tanks must be inspected and tested on a regular basis, which may only be done by an Inspection Body recognized by the National Competent Authority, Department for Transport, in the United Kingdom (DfT). The Vehicle Certification Agency (VCA) website provides information on Examination Bodies that have been assigned to execute various tasks relating to tank and/or pressure equipment inspection. All inspections, examinations, and tests are documented, and these documents must be kept for the duration of the tank’s life.
Cryogenic tank users and owners have legal obligations as well as a duty of care to ensure that their equipment is properly maintained and operated. The user must undertake routine safety inspections. Daily inspections must be carried out. A gas company will only fill a tank if it believes it is safe to do so. While in use, a small amount of icing and ice may be visible. Small levels of ice are not cause for concern, but the quantity of ice should be checked on a frequent basis. To minimize excessive ice collection, de-icing should be conducted if ice continues to accumulate.
Cryogenic tank repair and modification
Any repair or modification to a cryogenic tank should be performed only by a skilled repairer in accordance with the design codes to which it was constructed, while taking current regulations and legislation into account. Such repairs or adjustments must not affect the structural integrity or the operation of any protective systems. All repairs and adjustments must be documented, and the documentation must be kept for the rest of the tank’s life.
Cryogenic tank revalidation
Cryogenic tanks must be assessed on a regular basis to ensure that they are safe to use. The revalidation period, which shall not exceed 20 years, shall be determined by a Competent Person. Mobile tanks should be rented for a shorter period of time due to the nature of their function. When a tank is revalidated, a report is created that must be kept with the tank data for the life of the tank.
Security for Cryogenic Tanks
Liquid oxygen, liquid nitrogen, and liquid argon are examples of cryogenic liquids. Their respective boiling points are as follows:
- -297.3oF | -183oC • -320.4°F | -195.8°C
- Liquid Oxygen Nitrogen in liquid form
- -302.6°F (-185.9°C) Argon Liquid
- The sublimation point of liquid CO2 is -109.3°F | -78.5°C.
To prevent heat transfer and sustain very low temperatures, the storage vessel must be correctly constructed. The water capacity of commercially available liquid oxygen, liquid nitrogen, and liquid argon storage tanks ranges from 350 to 13,000 US gallons (1,325 to 49,210 liters). The storage tanks for Cryogenic Bulk Tanks may be vertical, spherical, or horizontal, depending on the location and consumption demands.
Cryogenic liquid storage tanks are made up of three major components:
• Vessel of Internal Pressure
A cryogenic vessel made of stainless steel or other materials with high strength when exposed to cryogenic temperatures.
• The Outer Vessel
A vessel made of carbon steel or stainless steel. Under normal operating conditions, this vessel maintains the insulation around the inner pressure vessel and can also maintain a vacuum around the inner vessel. Most of the time, the external vessel is not exposed to cryogenic temperatures.
• Insulation
The vacuum-sealed space between the inner and outer vessels, which is filled with several inches of insulating material. The vacuum and insulating material help to reduce heat transfer and, as a consequence, the boil-off of the liquid oxygen, liquid nitrogen, or liquid argon contained inside the vessel.
The inner vessel of a storage tank is typically designed to sustain a maximum allowed operating pressure of 250 psig (1724 kPa). Vessels may be designed for higher or lower working pressures, as well as for specific uses. The service pressure of the vessel may be adjusted.
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What exactly is steel pipe?
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Steel pipe has been manufactured in the United States since the early 1800s. Pipe is a hollow piece having a circular cross- section that is used to convey items such as fluids, gas, pellets, powders, and more. Steel pipes, on the other hand, are employed in a number of applications. They are used to transmit water and gas underground across cities and villages. They are also used in building to safeguard electrical wiring. Steel pipes may be both robust and light. As a result, they are ideal for bicycle frames. They are also utilized in the manufacture of vehicle components, refrigeration equipment, heating and plumbing systems, flagpoles, and street lighting, to mention a few.
The outer diameter (OD) and wall thickness are the two most essential dimensions for a pipe (WT). The internal diameter (ID) of a pipe is determined by OD minus 2 times WT (schedule), which defines the pipe’s liquid capacity. When we speak about pipe in our profession, we usually refer to it by its (ID) and schedule, such as 2-inch schedule 40 or 14 inch extra heavy. Sch. 40, Sch. 80, Sch. Standard (STD), Sch. XS/XH, and Sch. XXS are examples of walls or schedules. The majority of pipe is offered in lengths of 21 or 42 feet.
What exactly is Steel Tube?
The term tube refers to hollow portions that are round, square, rectangular, or oval and are utilized for pressure apparatus, mechanical applications, and instrumentation systems.
Steel tube may be manufactured using a variety of basic ingredients, including iron, carbon, manganese, vanadium, and zirconium. Tubing, like pipe, may be made as either seamless or welded. Seamless tubing is made from a solid piece of steel that is rolled into a circular form before being perforated and stretched to its full length. Consider a wad of play dough and shaping it into a cylinder. Then, using the leftover dough, press your finger into the center and lengthen it. That’s how it’s made, but it’s hot and whirling and all automated. Welded steel tube, on the other hand, is produced from coil. The coil is sliced and rolled into a circular form before the ends are soldered together. From then, the tubing may be cut to a certain length as round tubing or further distorted into different forms such as square, rectangular, oval, and so on.
Tubes are labeled with their outer diameter (OD) and wall thickness (WT), both in inches and millimeters. Buyers in our business often refer to the item they seek as a (OD) and a wall thickness (WT). Wall thicknesses such as 11 gauge, 1/4″, 3/8″ and 5/8″ are examples. Tubing is often available in lengths of 20, 24, 40, and 48 feet, although bespoke lengths are readily made.
Is it a tube or a pipe?
Although the names are often used interchangeably, there is one significant distinction between tube and pipe, notably in how the material is arranged and toleranced. Because tubing is utilized in structural applications, the outer diameter is the most essential dimension. Tubes are often used in applications requiring exact outer diameters, such as medical equipment. The outer diameter is significant because it indicates how much weight it can support as a stability element. Pipes, on the other hand, are often used to carry gases or liquids, therefore knowing the capacity is critical. Knowing how much water can flow through the pipe is critical. The pipe’s round form makes it effective at managing pressure from the liquid running through it.
Classification
Pipes are classified according to their schedule and nominal diameter. Pipe is normally ordered in accordance with the Nominal Pipe Size (NPS) standard, with a nominal diameter (pipe size) and schedule number specified (wall thickness). The schedule number on various sizes of pipe may be the same, but the actual wall thickness will vary.
Tubes are usually ordered by outer diameter and wall thickness, but they may also be ordered by OD & ID or ID and Wall Thickness. The wall thickness of a tube determines its strength. A gauge number specifies the thickness of a tube. Larger outer diameters are indicated by smaller gauge numbers. The interior diameter (ID) is a theoretical measurement. Tubes may be square, rectangular, or cylindrical in form, while pipe is always round. The circular form of the pipe distributes the pressure load equally. Pipes are used for bigger purposes and come in diameters ranging from 12 inch to several feet. Tubing is often utilized in applications that demand lower sizes.
Purchasing Tubing or Pipe
Tubing is usually ordered by outer diameter and wall thickness, but it may also be ordered by OD & ID or ID and Wall Thickness. Although tubing contains three dimensions (O.D., I.D., and wall thickness), only two of them may be defined with tolerances, while the third is purely theoretical. Tubing is often ordered and kept to stricter tolerances and requirements than pipe. Pipe is normally ordered in accordance with the Nominal Pipe Size (NPS) standard, with a nominal diameter (pipe size) and schedule number specified (wall thickness). Tubes and pipes may both be cut, bent, flared, and constructed – see our top 10 ordering advice for tubing and piping.
Characteristics
There are a few fundamental differences between tubes and pipes:
- Shape
Pipe is usually circular in shape. Tubes come in square, rectangular, and circular shapes.
- Measurement
Outside diameter and wall thickness are frequently selected when ordering tubes. Tubing is often held to stricter tolerances and requirements than pipe. Pipe is commonly ordered using the nominal pipe size (NPS) standard, with the nominal diameter (pipe size) and schedule number specified (wall thickness)
- Capabilities for Telescoping
Telescopes may be used on tubes. Telescoping tubes are ideal for applications that need many pieces of material to be sleeved or expanded within one another.
- Rigidity
Pipe is unyielding and cannot be shaped without the use of specialized tools. Tubes can be shaped with considerable effort, with the exception of copper and brass. Tubing can be bent and coiled without causing severe deformation, wrinkling, or breaking.
- Applications
Tubes are employed in applications that need a precise outer diameter, such as medical equipment. The outer diameter is significant because it indicates how much weight it can support as a stability element. Pipes are used to transfer gases or liquids, therefore knowing their capacity is critical. The pipe’s round form makes it effective at managing pressure from the liquid running through it.
- Metal Forms
Tubes may be cold or hot rolled. Only hot rolled pipe is available. They may both be galvanized.
- Sizing
Larger applications may be accommodated by size pipes. Tubing is often utilized in applications requiring tiny diameters.
- Strength
Tubes are more durable than pipe. Tubes outperform other materials in situations requiring durability and strength.
Types of steel pipe fittings
Pipe fittings are constructed from a variety of steels, including:
- Galvanized Steel: Galvanized steel is coated with layers of zinc by a chemical process to protect it against rust and corrosion. Galvanized steel is resistant to rust and corrosion and is widely used in the manufacture of pipe fittings and pipe. Galvanized steel also extends the life of pipe fittings. Galvanized steel fittings are offered in conventional diameters ranging from 8mm to 150mm. Galvanized pipe fittings are often made from seamless tube, forgings, rolling bar, or welded tube in accordance with particular specifications. Galvanized steel pipe fittings are used for all sorts of pipes inside a structure. They are also used in water distribution lines, but not in gas pipes.
- Carbon Steel: Carbon steel is far more durable and stronger than other types of steel, making it ideal for the manufacture of pipe fittings. Carbon steel, often known as simple carbon steel, is a malleable iron-based metal that contains mostly carbon and trace quantities of manganese and other metals. Steel may be cast to shape or worked into different mill forms from which final products are made, forged, stamped, machined, or otherwise shaped. Carbon is the primary hardening and strengthening ingredient in steel, providing maximum hardness and strength but decreasing ductility and weldability. Carbon steel pipe fittings are available in a variety of sizes and forms. Again, there are certain butt-weld carbon fittings with beveled edges that produce a shallower channel for the bead of weld that holds the component together. Butt-weld fittings are primarily utilized to link pipe sections when permanent and welded connections are needed. Butt-weld steel fittings are used to make elbows, reducers, tees, and other similar items. Carbon steel fittings are used in pipe systems that transport liquids or gases such as oil, water, natural gas, or steam. Aside from that, carbon steel fittings are in great demand in residential construction, commercial construction, electric power generation, petroleum refining, shipbuilding, and other industrial-use industries.
- Stainless steel: Because it is extremely resistant to oxidation and corrosion in a variety of natural and man-made settings, stainless steel is frequently utilized in the manufacture of pipe fittings. Stainless steel is a ferrous alloy that contains at least 10% chromium. It is critical to choose the correct grade of stainless steel for a certain application. Stainless steel is used in a variety of pipe fittings such as tees, unions, elbows, and so on. Household pipes are often fitted with stainless steel fittings.
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An Overview of Cogeneration Operations
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What Is the Process of a Cogeneration Plant?
When a power plant creates electricity, it also generates heat. If the plant emits that heat into the atmosphere as exhaust, it constitutes a massive waste of energy. The majority of the heat may be collected and reused. When heat is repurposed, the power plant operates as a cogeneration system.
The cogeneration process may improve total energy efficiency, with typical systems achieving efficiency levels ranging from 65 to 90 percent. Businesses that employ cogeneration may reduce greenhouse gas emissions and pollutants while lowering operating costs and increasing self-sufficiency.
The History of CHP
Thomas Edison, widely regarded as America’s greatest inventor, planned and completed Pearl Street Station in New York City in 1892.
The idea of combining heat and electricity is not new. CHP was utilized in Europe and the United States as early as 1880 to 1890. Many companies employed their own coal-fired power plants to create the energy that powered their mills, factories, or mines during those years.
As a byproduct, the steam was utilized to provide thermal energy for different industrial operations or to heat the area.
In 1882, Thomas Edison planned and constructed the first commercial power plant in the United States, which also occurred to be a cogeneration facility. The thermal waste of Edison’s Pearl Street Station in New York was sent as steam to local factories, as well as heating neighboring buildings.
The Rise and Fall of CHP Utilization
CHP systems provided around 58 percent of the total on-site electrical power generated in industrial enterprises in the United States in the early 1900s. According to “Cogeneration: Technologies, Optimization, and Implementation,” edited by Christos A. Frangopoulos, that number had dropped to barely 5% by 1974.
There were several explanations for the precipitous drop.
Electricity from central power grids grew more dependable and less expensive to purchase, while fuel, such as natural gas, became more affordable, making privately owned coal-fired on-site power plants less appealing. In addition, the government raised the quantity and scope of rules and limitations pertaining to power generating. However, as fuel prices surged in 1973 and public awareness of the detrimental impacts of pollution expanded, cogeneration regained prominence.
Why Should You Use Cogeneration?
Cogeneration has a number of advantages. The primary motivations for using CHP are to save energy and money by lowering fuel use. Existing CHP customers in the United Kingdom, for example, save 20% on their energy bills.
When fuel energy is turned into mechanical or electrical energy via CHP, the majority of the heat emitted is not squandered. Less fuel is required to perform the same quantity of productive work as a typical power plant.
This lower fuel consumption has various advantages, including:
- Reduced gasoline expenses
- Fuel storage and transportation requirements are reduced.
- Emissions reduction — CHP is one of the most cost-effective methods of reducing carbon emissions.
- Machine wear is minimized as a result of reduced pollution exposure.
- Another advantage is security.
Cogeneration is regarded as a secure power source since it produces stand-alone electricity that is not reliant on a municipal power system. A cogeneration-powered firm may operate off-grid or simply supplement to meet a rise in power demand.
The Basic Elements of a Cogeneration Plant
A typical cogeneration facility, at its most basic, consists of an electricity generator and a heat-recovery system. Here are some fundamental components of a CHP system:
- Prime movers: These machines convert fuel into heat and electrical energy, which may then be utilized to create mechanical energy. Gas turbines and reciprocating engines are examples of primary movers.
- Mechanical energy is converted into electrical energy by an electrical generator.
- System of heat recovery: Heat is captured from the primary mover.
- Heat exchanger: Ensures that the collected heat is used.
What Are the Fuels Used in Cogeneration Plants?
Cogeneration facilities may run on a range of fuels, including natural gas, diesel, gasoline, coal, and biofuels.
Biofuels used in cogeneration are generally produced from renewable resources such as landfill gas and agricultural solid waste.
CHP systems are classified into two kinds.
- Cycle plants at the top: The production of power is the first step in a topping cycle system.
- Plants in the bottoming cycle: The first step is to create heat – waste heat generates steam, which is subsequently utilized to generate electricity.
Bottoming cycle plants may be found in businesses that employ very hot furnaces. They are less prevalent than topping cycle plants, because to the ease with which surplus power may be sold.
Who Can Benefit from Cogeneration?
Heat and electricity are in high demand in the industrial sector. Metal makers, for example, largely employ heat, while others mostly use electricity. Other businesses need varied amounts of heat and power.
A recycled energy system may help in any circumstance. A factory that uses more heat than electricity may sell the heat to a utility, and surplus power can be sold in the same way.
There are three sizes of cogeneration plants:
- Small: The military, colleges, and non-utility corporations run several small CHP plants in the United States and Canada. What they have in common is a strong demand for energy, as well as a pressing need for dependable and self-sufficient energy sources. According to a Scientific American article, a computer networking firm that uses CHP saves roughly $300,000 in energy expenditures each year.
- Medium: The market for medium-scale cogeneration systems is expanding. According to David Flin’s “Cogeneration: A User’s Guide,” medium-scale units produce 50 to 500 kW of electricity. This category includes industries that demand significant heat and energy loads, such as hospitals and hotels.
- Large: Large CHP plants may be found in energy-intensive industries like as oil refineries and food processing plants. These may generate 500 kW or more of electricity.
Cogeneration makes sense when the necessary circumstances are met. It’s a dependable and efficient solution to offer on-site electricity that’s both inexpensive and ecologically friendly.
A thorough knowledge of steam-urbine operating and power generating costs may aid in increasing total cogeneration profitability. This article explains the fundamental economics of cogeneration.
Cogeneration enables a facility to lessen its dependency on external electrical energy purchases by utilizing steam to spin turbines and create electricity. This article outlines best practices for steam cogeneration system selection, operation, integration, and control.
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LNG Plant Safety
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The use of natural gas as a cleaner-burning alternative to other fossil fuels is becoming more popular as the globe works toward decarbonization. Natural gas may be converted to liquefied natural gas (LNG) for storage and transportation purposes, which is safer. Facilities that handle LNG, such as liquefaction plants, regasification plants, and storage facilities, are still connected with the possibility of injury or death from the gas. Understanding these dangers is critical to putting in place the required preventative and mitigation measures to protect people and property.
When it comes to LNG plants, an uncontrolled leak of a cryogenic, poisonous, or combustible fluid is a major concern. Releases of this kind might originate in a variety of locations within the industrial system. When these releases occur, the consequences are determined by what they expose and whether or not they are ignited. For the sake of simplicity, the most significant LNG plant risks may be divided into seven categories.
Natural gas liquids (LNG) take up just 1/600th of the volume of natural gas in its gaseous condition, but they maintain all of the energy potential. As a result, the energy potential of a certain volume of LNG is much larger than the energy potential of a same amount of natural gas in its gaseous condition. The intrinsic features of LNG, as well as the design and operation of LNG facilities and transportation modes, are all taken into consideration when addressing the safety of LNG facilities.
Land-based LNG facilities use impoundment structures surrounding LNG tanks and pipes, which are intended to limit the spread of LNG in the event of an accidental leak. When a release occurs, fire and vapor suppression devices are installed in order to limit the repercussions of the event. Automated fire suppression and vapor suppression systems are activated by gas detectors, fire detectors, temperature sensors, and other sensors. Firefighters may employ water spray to cool heat-affected exposures, or high-expansion foam to lessen the effect of radiant heat on certain exposures in the case of a fire. Vapor fences are constructed at certain sites to prevent fumes from escaping and spreading to neighboring property boundaries. In addition, vacuum jacketed pipe offers an extra layer of protection in the event that the inner pipe ruptures. When operating parameters exceed the usual range, emergency shutdown mechanisms are activated to prevent further damage. The operator of an LNG plant must establish and adhere to thorough maintenance protocols in order to maintain the integrity of the facility’s different safety measures.
Prior to beginning operations, the LNG plant operator must develop precise operating procedures that outline the usual operating parameters for all of the facility’s machinery. Any time a piece of equipment is upgraded or replaced, all associated processes must be examined and, if required, adjusted in order to maintain the system’s integrity. All staff are required to undergo training in operations and maintenance, security, and firefighting before they may begin working. Coordination with local authority and informing them of the sorts of fire control devices accessible inside the facility are essential tasks for an owner or operator. Aside from that, federal requirements need a high level of security for the facility, which includes access control systems, communications systems, enclosure monitoring, and patrolling.
Risks associated with LNG installations include:
Temperature
- It is possible to have cryogenic liquid releases that induce embrittlement if they come into contact with materials that are not intended to manage such releases, and freeze burns if they come into contact with persons.
- Turbines, boilers, and engines generate electricity and heat by releasing hot vapor into the atmosphere.
Toxic
- gas emissions such as hydrogen sulfide (H2S) or ammonia are a concern.
Asphyxiation
- Releases of nitrogen oxide, carbon monoxide, carbon dioxide, or sulfur dioxide that replace oxygen in an area and may result in asphyxiation are classified as asphyxiation.
Pool Fire
- Liquid discharges that collect in a pool on the ground or in water and ignite, resulting in a pool fire that might burn for hours or days.
Jet fire
- Pressurized gas or liquid is released and ignites, resulting in a high heat flux jet fire with a fast rate of spread.
Vapor dispersion/flash fire
- Gas or liquid discharges that cause a flammable cloud to build in an open area and then ignite, resulting in a brief and powerful flash fire that is hazardous to the surrounding environment.
Explosion of a vapor cloud (VCE)
- An explosion and pressure wave are caused by the discharge of gas or liquid, which causes a flammable cloud to build in a crowded or confined region and then ignites.
Research and Studies about LNG Safety
Through its Pipeline Safety Research and Development programs, the Federal Highway Administration (PHMSA) sponsors LNG research. The following LNG projects are underway:
- DTRS56-04-T-0005, Modeling and Assessing a Spectrum of Accidental Fires and Risks in an LNG Facility.
- DTPH5615T00005, Comparison of Exclusion Zone Calculations and Vapor Dispersion Modeling Tools.
- DTRS56-04-T-0005, Modeling and Assessing a Spectrum of Accidental Fires and Risks in an LNG Facility.
- DTPH5615T00008, Statistical Review and Gap Analysis of LNG Failure Rate Table (Statistical Review and Gap Analysis of LNG Failure Rate Table)
An Overview of the History of Vapor Cloud Explosions (VCE)
The recent availability of domestic shale gas has resulted in the construction of LNG export facilities that will be able to liquefy massive amounts of natural gas. When it comes to liquefying natural gas, these facilities need substantially bigger volumes of refrigerants than are generally required in peak shaving or small-scale operations. ethane, propane, ethylene, and iso-butane are among the heavy hydrocarbons found in most refrigerants gases and mixes used in export facilities, and they are referred to as heavy hydrocarbons. These gases are comparable to gases that have caused VCEs at petrochemical sites in the past. However, the Pipeline and Hazardous Materials Safety Administration (PHMSA) is not aware of any valid reports of outdoor natural gas vapor cloud explosions and does not think that there is a danger of vapor cloud explosions (VCEs) owing to the emission of methane in an open area.
The Review of Vapor Cloud Explosion Incidents report was sponsored by the Pipeline and Hazardous Materials Safety Administration (PHMSA) with the primary goal of improving scientific understanding of vapor cloud development and explosion in order to more reliably assess hazards at large liquid natural gas (LNG) export facilities. We must emphasize that the LNG export facilities in operation today have several levels of security in place that were not in place at the sites described in the study. Many of the lessons learnt from these incidents have resulted in the implementation of safety measures that are now needed in LNG installations. Specifically, the purpose of reviewing the specific incidents in this report is to examine the extensive forensic evidence that is available, which provides the information necessary to investigate how the vapor cloud formed and ignited, the amount of overpressure exerted, and other information about the mechanism of VCE.
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LNG Plant Commissioning Process
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Commissioning
What is the process of commissioning?
In some ways, the commissioning process may be seen of as a quality assurance procedure that allows the construction project teams to produce a building that is fully operational and meets all of the specifications. This is a critical contrast between the delivery of a physical structure and the delivery of a facility in complete operating order that is really functional for persons, companies, and the environment as a whole.
The idea of full functioning order necessitates the completion of a number of goals, and there are several elements that influence the performance of a structure and its engineering services in general. Design characteristics that will allow for verification activities such as functioning, pressure testing, and flow regulation are included into the process in general. Procedures that will cover prescribed settings to work, system regulation, and performance testing are also included. The commissioning process must also include user and operator training, as well as the creation of critical system documentation, in order to properly support building operation and usage in the future.
Stages of the commissioning process
In the commissioning process, there are eight steps, which are as follows: preparation, design, pre-construction, construction, commissioning of services, pre-handover preparation, first occupation preparation, and post-occupancy care.
A building’s actual energy consumption in the first year might be up to 25 percent greater than the estimate made during the design stage, and this is ascribed to insufficient commissioning and handover procedures during construction. doing the task successfully
All of the steps listed above, as well as beginning the commissioning process as soon as feasible, assure cost-effective project completion while also allowing the building’s inhabitants to optimize equipment utilization long after the construction process is complete, according to the manufacturer.
The following is a summary of the actions that were carried out at each stage:
Stage 1 – Planning and Preparation:
- Assemble the commissioning team.
- Examine lessons learned and experiences gained from similar buildings and projects.
- Clearly define the performance outcomes expected by the client and the end user.
- Contribute to the development of a design brief that accurately represents the required performance
Stage 2 – Design:
- Review the performance results with the client
- Ensure that the commissioning process activities have been clearly established
- Ensure that the performance outcomes reflect any modifications to the system/project design
Stage 3 – Pre-Construction:
- Ensure that the contractors understand the performance requirements.
- Verify that the trade contractors have the capability to satisfy the requirements of the commissioning process.
Stage 4 – Post-Construction:
- Develop a thorough commissioning program.
- Carry out pre-commissioning work, which includes checking the installation work and running static tests. Verify and record that the desired performance objectives have been met.
- Ensure that progress on the creation of the O&M manuals is made on a consistent basis.
Stage 5 – Commissioning of Engineering Services:
- Perform the initialization of systems and ensure that they are operational.
- Verify that the necessary performance and outcome objectives have been met or exceeded.
- Performance testing of the building, equipment, and engineering services should be carried out. Make that the specified performance levels have been met and record this in writing.
- Include members of the facilities management team in the commissioning process.
- Gather all of the commissioning checklists and test papers in one place.
Stage 6 – Preparation for Handover
- Examine the quality of the documentation evidence gathered throughout the commissioning process’s activities.
- Maintain completeness and accuracy of all necessary statutory paperwork.
- Provide users and operators with instruction and guidance.
- Create and distribute user manuals for the building.
- Examine the needs of the customer and respond to any discrepancies.
7. Initial Occupation:
- Introduce the user to their equipment or premises and demonstrate how it works.
- Assist the facilities management team with the earliest phases of the building’s operation
- Refresh commissioning records in line with and after approval of any revisions
- Update the operation and maintenance manuals to reflect any modifications that have been authorized.
Stage 8 – Post-occupancy care
- Seasonal commissioning.
- Fine tuning of the building and its engineer services.
- Building performance evidence is collected and reviewed.
- Commissioning records and operation and maintenance manuals are updated in accordance with seasonal commissioning and fine-tuning work.
- Lessons learned are produced by comparing building performance to design intent, client stakeholder expectations and industry benchmarks.
Documentation for the commissioning and transfer of services
Building handover information is incomplete without the inclusion of commissioning process verification and test records, which are crucial components of the handover information. It is not only important to have proof that the desired performance objectives have been reached, but it is also important to have knowledge about the method in which the system has been configured for operation in case any enhancement, modification, or fine-tuning work is needed after handover.
The summary commissioning process is the post-installation procedure that occurs prior to the start-up and operation of the system. It assures that the equipment that has been installed and linked will operate at peak efficiency from the beginning, while also validating that the performance of the LNG equipment has been reached. It is possible to complete this procedure on site at the client’s option, and it includes a complete system assessment and optimization, as well as staff training and demonstration, as well as supporting documentation to support equipment usage now and in the future.
Starting up and commissioning your natural gas processing facility is a time-consuming process.
Start-up and commissioning are the last stages of preparations required before a natural gas processing plant or comparable processing facility can be put into production. The operations carried out throughout the start-up and commissioning phases should guarantee that the facility will function safely and in accordance with its design specifications and specifications.
The majority of EPC turnkey contracts include this phase as part of the overall package. Engineers, field technicians, and operations people will comb over every inch of the plant, inspecting hundreds of connections, instruments, valves, and other pieces of equipment. This time- and labor-intensive procedure will take many months. Depending on how sophisticated the facility is, it might take weeks or even months to finish.
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LNG Plant Maintenance and Integrity
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What does the term “asset integrity” means in oil and gas industry?
Asset integrity, also known as asset integrity management systems (AIMS), is the term used to describe an asset’s ability to operate efficiently and accurately while also protecting the health and safety of all personnel and equipment with which it interacts – as well as the measures in place to ensure the asset’s long-term availability. Throughout the life cycle of an asset, from its conception through decommissioning and replacement, asset integrity must be maintained.
Asset integrity management consists of a number of components
Much of the oil and gas industry’s infrastructure is already nearing or has already reached the end of its operational life expectancy, if not already beyond it. Because the cost of replacing assets, as well as the resulting turnaround time, has become unacceptably expensive for so many facilities, asset integrity has now surpassed concepts such as OPEX and Agile as the watchword on everyone’s lips, according to a recent study.
There is an increase in challenges such as vessel inspection, which is a significant contributor to production downtime; and corrosion under insulation, which is a frequent cause of sudden shutdowns; and taking the step to employ new solutions is becoming a necessity in many locations, particularly offshore.
The importance of the human factor
Asset integrity is based on the assumption that the vast majority of people within the organization will carry out their responsibilities correctly. However optimistic this may sound, the vast majority of maintenance, inspection, and data management activities are carried out with the best of intentions. Things, on the other hand, are not always accomplished completely or in the shortest amount of time available. It is unlikely that simple measures, such as increased inspection frequency, can uncover every overlooked problem. It is also unlikely that employees, who are required to increase their inspection labor or who are involved in missed problems, will be enthused about the task at hand.
Some indicators that everything is not well in the field of asset integrity management and inspection include the following:
- Teams believe that any concerns they have regarding health and safety, or the condition of equipment are not taken seriously, resulting in an atmosphere where errors are not even reported as a result of this perception.
- Any modifications to asset integrity plans, or even the fundamental operation of the facility, are only implemented after a large-scale event.
- An inability to distinguish underlying causes from basic defect reports, which often leads to personnel being lulled into an unwarranted feeling of security and overstating the extent to which the facility is safe and operating.
- Tactic knowledge, rather than a physical and immediately available set of rules, is relied upon in the context of AIM and reporting problems.
- In the world of maintenance contractors, there is a “lowest bidder” mentality that prevails, and knowledge of and passion for asset integrity are not highly rewarded.
The very real outcome of this kind of environment is that nothing occurs in any meaningful way. Till a significant occurrence forces an organization to adjust, which is typically at tremendous expense, asset integrity is seen as a barely acceptable inconvenience, a type of obstacle to getting the job done properly.
Identifying and filling up the gaps in asset integrity management systems
Despite the fact that there are more AIM systems on the market now than at any previous time in history, there are still no one-size-fits-all solutions available. Although no inspection plan or database can possibly address all of the AIM concerns that might occur, integrity systems are nevertheless seen as distinct from the rest of the organization’s activities. Employees may be reluctant to accept responsibility for their actions, seeing the suite of AIM packages as an effort by the corporation to police them rather than as an intrinsic part of their job description.
The holes in AIM packets must be filled with the vigilance of the same persons from whom they are intended to protect, but a creative strategy may be required to guarantee that this message is received by the intended recipients.
What is the significance of asset integrity management?
A leak from the Piper Alpha oil platform in the North Sea occurred over the period of 22 minutes on July 6, 1988, causing an explosion that killed 167 of the rig’s 229 employees. The leak occurred over the length of 22 minutes. Among other things, this accident is seen as a watershed point in the development of current approaches to both EH&S and AIM in the oil and gas industry, not least because it resulted in each offshore operator investing £1 billion in safety measures.
The United Kingdom government subsequently launched a public enquiry, which was completed in 1990 and made 106 recommendations on how to implement HS&E and AIM initiatives more effectively in the future – all of which were approved by the oil and gas sector. So, given that we are living and working in an era when significant AIM attempts are being made, what areas should individuals be concentrating their energies on?
Developing a strategic approach to AIM
According to research performed by Oil & Gas IQ, oil and gas operators are increasingly pursuing price-responsive strategies as well as the optimization of existing assets in order to remain competitive. These enterprises, particularly those operating in the North Sea, are now re-evaluating their business processes in order to stay afloat. 51 percent of oil and gas experts are now working on installations that are more than 20 years old and have been in service for more than a decade — with fewer than a third working on installations that are in their first ten years of operation.
More than half of asset integrity professionals have had their budgets reduced, and the average grade given to those professionals’ own firms’ asset integrity management (AIM) rating was 5.4 out of a possible 10. Only 52% of respondents believed that their job load was manageable in terms of achieving objectives and preserving safety – despite the fact that the vast majority worked with a meager budget of less than £250,000. Unsurprisingly, asset integrity professionals report that the two most pressing concerns they face are keeping assets under budget and the age of the assets themselves. The lack of communication between departments in oil and gas businesses is by far the most serious fault that has been identified, followed by a lack of a safety culture in the industry. There is definitely work to be done.
RBI: Risk-Based Inspection
It is now more necessary than ever to ensure that an effective system of identification is in place, especially since the industry’s infrastructure is rapidly aging and becoming one of its key issues. For example, more than half of pipelines in the United States are at least 50 years old, with 3,300 incidents, including the worst spill in US pipeline history, eighty fatalities and almost 400 injuries in only the last five years. Despite the fact that it may seem apparent, maintaining integrity, preventing corrosion, and repairing damage is similar to seeing an iceberg from a distance.
It is nearly impossible to implement damage mitigation techniques without the assistance of dedicated and experienced professionals. For every readily apparent symptom of corrosion or asset instability, there are dozens of hidden issues: hydrogen attack, high-temperature tempering, thermal fatigue, metallurgy issues, internal system corrosion, and so on. Once it has been determined that a comprehensive examination is required, the following step is to put it into effect.
Among the methods available are risk-based inspections (RBIs), which demand that the risk be reduced while putting in the least amount of work possible in order to expedite the process and free up more time. The problem is that there are an almost limitless number of methods in which we may carry out our maintenance – and with so many hazards (such as calibration uncertainty or equipment accessibility), quantification is just not viable. In order to determine where on the quantitative/qualitative spectrum a corporation is located, it must first choose whether it will depend more heavily on specialists or on data.
Companies will operate in either a reactive or a proactive mode, depending on how effectively or poorly they foster their dependability cultures. It goes without saying that you want to be proactive. Because of a failure to foresee and monitor for hidden difficulties, you will only be able to respond after problems have developed, which will cost you significantly more money in the long run and reward those who have shown the ability to react swiftly. Instead of enhancing the culture, this positive reward serves to promote the tendency to react rather than act.
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Energy Development: Oil & Gas from start to finish
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Due to their position as the world’s principal fuel sources, oil and natural gas are important sectors in the energy industry and have a significant impact on the global economy. The processes and systems involved in the production and distribution of oil and gas are very complicated, capital-intensive, and reliant on cutting-edge technology to function properly. History has shown that natural gas is closely associated with oil, mostly due to the production process or the upstream part of the industry. Natural gas was seen as a nuisance throughout most of the industry’s history, and it continues to be flared in huge amounts in various regions of the globe, notably the United States, even now. Natural gas has risen to a more significant position in the world’s energy supply as a result of the shale gas production in the United States, as previously noted, as well as the fact that it emits less greenhouse gases when combusted as compared to other fuels such as oil and coal.
There are three main segments in the industry, which are as follows:
- Upstream – refers to the business of oil and gas exploration and production, as opposed to downstream.
- Midstream process – Transportation and storage
- Downstream – activities include refining and marketing.
With an estimated $3.3 trillion in revenue generated yearly, the oil and gas business is one of the world’s biggest industries in terms of monetary value, ranking second only to manufacturing. Oil is critical to the global economic framework, particularly for the world’s top producers, which include the United States, Saudi Arabia, Russia, Canada, and China, as well as other countries.
If you are an investor seeking to get into the oil and gas business, you may be intimidated by the intricate vocabulary and specific measurements that are utilized across the industry. This introduction is intended to assist anybody interested in learning about the foundations of organizations operating in the oil and gas industry by introducing essential ideas and measurement standards used in the industry.
About Hydrocarbons
Crude oil and natural gas are made up of hydrocarbons, which are naturally occurring compounds found in the earth’s crust and rock formations. They are formed by the compression of plant and animal remnants in sedimentary rocks such as sandstone, limestone, and schist. These organic raw materials are used in the production of plastics and other manufactured products.
As a result of sedimentary rock formation in ancient seas and other bodies of water, the sedimentary rock itself may be described as follows: The rotting carcasses of plants and animals were incorporated into the developing rock when layers of silt were formed on the ocean bottom. After being subjected to appropriate temperatures and pressure ranges deep under the earth’s crust, the organic material finally converts into oil and gas.
Being lighter in weight than water, oil and gas move more quickly through permeable sedimentary rock toward the earth’s surface than water. The formation of an oil and gas reservoir occurs when hydrocarbons are trapped behind less-permeable cap rock. We get our crude oil and natural gas from these oil and natural gas resources.
Drilling through the cap rock and into the reservoir is used to bring hydrocarbons to the surface. A profitable oil or gas well may be created after the drill bit has reached the reservoir and the hydrocarbons can be brought to the surface by pumping them up to the surface. The well is classed as a dry hole if the drilling effort does not result in the discovery of economically viable amounts of hydrocarbons. A dry hole is normally closed and abandoned.
Methods of Exploration
The presence of visible surface characteristics such as oil seeps, natural gas seeps, and pockmarks (underwater craters formed by escaping gas) serve as the most fundamental evidence of hydrocarbon formation in the environment (be it shallow or deep in the Earth). The majority of exploration, on the other hand, is dependent on very advanced equipment to discover and estimate the extent of these deposits, which is done via the use of exploratory geophysics. Localized gravity surveys, magnetic surveys, passive seismic surveys, and regional seismic reflection surveys are used to discover large-scale characteristics of the sub-surface geology in areas suspected of containing hydrocarbons in the first instance. Features of interest (known as leads) are subjected to more detailed seismic surveys, which are based on the principle of the time it takes for reflected sound waves to travel through matter (rock) of varying densities, and which use the process of depth conversion to create a profile of a substructure’s structure. Finally, when a prospect has been found and analyzed, and if it meets the oil company’s selection criteria, an exploratory well is drilled in an effort to ascertain definitely whether or not there is oil or gas there. The use of electromagnetic technologies may help to lessen the danger of accidents on the ocean floor.
Oil exploration is a costly and high-risk process that requires extensive capital investment. Offshore and remote region exploration are often only performed by major enterprises or national governments with significant financial resources. Deep sea oil wells may cost up to US$100 million or more, whereas shallow shelf oil wells (such as those in the North Sea) can cost as little as US$10 million. The hunt for onshore hydrocarbon reserves is carried out by hundreds of smaller firms throughout the globe, with some wells costing as little as US$100,000.
Aspects of a petroleum exploration potential
A prospect is a prospective trap that geologists feel may contain hydrocarbons and so should be explored. First and foremost, a large amount of geological, structural, and seismic study must be conducted in order to transform the probable hydrocarbon drill site from a lead to an actual prospect. For a prospect to be successful, four geological elements must be present, and if any of these factors are absent, neither oil nor gas will be present.
- Source rock – When organic-rich rock such as oil shale or coal is subjected to high pressure and temperature over an extended period of time, hydrocarbons form.
- Migration – The hydrocarbons are expelled from source rock by three density-related mechanisms: the newly matured hydrocarbons are less dense than their precursors, which causes over-pressure; the hydrocarbons are lighter, and so migrate upwards due to buoyancy, and the fluids expand as further burial causes increased heating. Most hydrocarbons migrate to the surface as oil seeps, but some will get trapped.
- Reservoir – The hydrocarbons are contained in a reservoir rock. This is commonly a porous sandstone or limestone. The oil collects in the pores within the rock although open fractures within non-porous rocks (e.g., fractured granite) may also store hydrocarbons. The reservoir must also be permeable so that the hydrocarbons will flow to surface during production.
- Trap – The hydrocarbons are buoyant and have to be trapped within a structural (e.g., Anticline, fault block) or stratigraphic trap. The hydrocarbon trap has to be covered by an impermeable rock known as a seal or cap-rock in order to prevent hydrocarbons escaping to the surface
Exploration carries a risk
Because hydrocarbon exploration is a high-risk venture, conducting a thorough risk assessment is essential for effective project portfolio management. It is difficult to quantify exploration risk, but it is often characterized as the degree of trust that can be placed in the existence of the critical geological elements, which were addressed above. Based on data and/or models, this level of confidence is often shown on Common Risk Segment Maps (CRSM) (CRS Maps). High confidence in the existence of critical geological causes is often represented by the color green, whereas low confidence is represented by the color red. The maps are also known as Traffic Light Maps, and the whole method is referred to as Play Fairway Analysis in certain instances (PFA). The purpose of such processes is to compel the geologist to conduct an objective evaluation of all relevant geological parameters. Furthermore, it produces straightforward maps that can be understood by non-geologists and managers, which may be used to inform exploration choices.
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Oil and Gas Production Technology
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The burst of production growth in the United States, often known as the “Shale Revolution,” was made possible by the introduction of new technology in the oil and natural gas industries. It was formerly prohibitively costly for oil and gas companies to extract reserves of oil and gas from low-permeability geological formations. However, a combination of horizontal drilling and hydraulic fracturing has made it possible for these deposits to be accessed. Up until quite recently, the United States was the greatest user of oil in the world, accounting for 25 percent of the demand that was met worldwide. New developments in the oil and gas industry in the United States have stimulated economic recovery from the financial crisis that occurred in 2008. This has been accomplished through the creation of new jobs, increased investment in oil- and gas-producing regions, and decreased prices paid by consumers for gasoline. Policymakers are concerned that a significant decrease in the amount of petroleum the United States imports would have geopolitical repercussions that go beyond an improvement in the nation’s energy security and might result in altered diplomatic ties with nations that produce oil. In a similar vein, there is some cause for worry over the possibility for lower export profits for traditional producing nations to both contribute to instability and pose a possible danger to the security interests of the United States. These worries, on the other hand, are unjustified because of a common misunderstanding of the function that oil plays in the process of forming diplomatic connections.
The United States is not the only country in which innovative methods of oil and gas extraction are making their way into use. As a result of price signals, multinational oil firms have begun to explore unconventional hydrocarbon resources in Canada, South America, and Africa. These businesses are looking for larger profits by expanding their operations into new territories. Tar sands drilling and deepwater water drilling are two of the most notable examples of these newly developed production methods. In this part of the article, we will examine the many new kinds of technology for the production of oil and gas that are altering the global energy landscape, as well as the consequences these technologies have for the environment.
The Developmental Process, Broken Down into Its Components
The process of extracting oil and gas may be broken down into four distinct phases:
- exploration
- well development
- production
- site abandonment
The search for rock formations that are connected with oil or natural gas resources is part of the exploration process, which also includes geophysical prospecting and/or exploratory drilling.
After exploration has located an economically recoverable field, the next step is well development, which involves the construction of one or more wells from the beginning (called spudding) to either abandonment if no hydrocarbons are found in sufficient quantities or to well completion if hydrocarbons are found in sufficient quantities. Well development occurs after exploration has located an economically recoverable field.
The process of production involves the extraction of hydrocarbons, the separation of a combination including liquid hydrocarbons, gas, water, and particles, the elimination of ingredients that are not suitable for sale, and the subsequent sale of liquid hydrocarbons and gas. It is common practice for production sites to process crude oil coming from many wells. Oil is almost usually processed in a refinery; natural gas, on the other hand, may be treated to remove pollutants either in the field or at a natural gas processing plant. Both of these facilities are referred to as natural gas processing plants.
When a freshly drilled well does not have the potential to produce profitable amounts of oil or gas, or when a producing well is no longer economically feasible, site abandonment includes capping the well (or wells) and restoring the site.
Innovative Methods and Equipment for Drilling
Vertical drilling has always been the standard method for oil and gas wells. Operators have been able to save time, cut down on their operating expenses, and have a smaller effect on the environment as a direct result of technological improvements. The following methods are included in the next generation of drilling technologies:
Horizontal Drilling
The drilling process for horizontal wells begins with a vertical well that is then turned horizontal inside the rock of the reservoir in order to provide a larger opening to the reservoir. These horizontal “legs” may be more than a mile in length; the greater the exposure length, the greater the amount of oil and natural gas that can be drained, and the quicker it can flow. Horizontal wells are appealing for a number of reasons: (1) they can be utilized in circumstances in which conventional drilling is either not possible or not cost effective; (2) they reduce surface disturbance because they require fewer wells to reach the reservoir; and (3) horizontal wells can produce anywhere from 15 to 20 times as much oil and gas as a vertical well.
Drilling in Multiple Directions
There are instances when oil and natural gas deposits are situated in distinct strata of the earth’s crust. Drilling in many directions at once gives operators the ability to access deposits located at varying depths. Multilateral drilling is one kind of this drilling. This results in a significant boost in output from a single well while simultaneously lowering the total number of wells that need to be dug on the surface.
Extended Reach Drilling
By using drills with extended reaches, producers are able to access deposits that are located at large distances from the drilling rig. This enables producers to access oil and natural gas resources below the surface of places that are not suitable for drilling vertical wells, such as locations that are not yet developed or areas that are ecologically sensitive. Wells can now extend out over 5 miles from the surface position, and hundreds of wells may be drilled from a single location, decreasing surface effects. Additionally, wells can now reach out over 5 miles from the surface
Drilling on Complicated Routes
When trying to target several accumulations from a single well site, complex well routes might have many twists and turns to attempt to navigate around obstacles. When compared to digging many wells, the use of this technique may be more efficient financially, generate less waste, and have a less impact on the surface.
Advantages of Directional Drilling Technologies (Advanced Drilling Methods)
- Enhance oil production while simultaneously building up reserves.
- Natural cracks that intersect one another yet are inaccessible through vertical wells
- preventing the beginning of gas or water coning, which is a phrase used to describe the process that underlies the upward movement of water and/or the downward movement of gas into the perforations of a producing well, in order to increase the amount of oil that is produced from the well.
- Increasing output from low-volume or low-pressure reservoirs
- Improving the “sweep efficiency” of waterflooding, also known as the capacity, to extract more oil from a reservoir after the first extraction, is necessary for reservoirs that are injected with fluids in order to boost oil or gas output.
Unconventional Natural Gas
The conventional oil well is not the only way to extract unconventional oil resources; there are other alternative options. However, the oil sands, tar sands, heavy oil, and oil shale resources mentioned above are not covered by the information provided on this page. Natural gas production using unconventional methods is distinguished by the presence of distinctive geologic characteristics, which increase the difficulty of extracting natural gas from reservoirs. Formations such as tight gas, shale gas, hydrates, and coalbed methane are examples of those that are typically more impermeable or have a lower overall permeability.
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