Pipeline Stress Analysis is quite different from normal plant piping stress analysis. Normally Pipelines run kilometers in length for transferring oil, gas, water, or sewer. There are two types of pipelines. Liquid Pipelines and Gas pipelines. Pipeline Stress Analysis of liquids is governed by ASME B31.4 whereas the same design standard for gas pipelines is dictated by ASME B31.8.
All my previous articles on this website describe the stress analysis methodology of piping systems using Caesar II based on ASME B31.3. But I received requests from many pipeline engineers to describe the pipeline stress analysis methodology. So in this article, we will explore the required steps for stress analysis of a pipeline system.
Pipeline Stress Analysis Considerations
The most fundamental difference between pipeline and plant piping is the very long length of the pipeline. A pipeline with kilometers in length produces a very large amount of expansion even though the design temperature of pipelines is normally less as compared to plant piping. A reasonable estimate of the movement and its interaction with the end resistance force afforded by connecting piping and equipment are very important aspects of designing a pipeline.
Pipeline General Arrangement Drawings are used for showing pipeline routes. These pipelines in most cases do not run parallel to any given direction. Refer to Fig. 1 for a typical sample of pipeline GA/Route plan drawing.
Fig. 1: Sample GA for pipeline Stress Analysis
A large amount of pipeline movements are caused due to pressure elongation, also known as the bourdon effect. For plant piping bourdon effect is normally ignored but for pipelines, the pressure elongation is significant and is considered. So,
The total elongation for pipelines=Temperature Elongation+Pressure Elongation.
Pipeline stress Analysis is not as stringent as plant piping as the allowable values are much more as compared to plant piping allowable values.
Hydro-test pressure for pipeline stress analysis is normally considered as 1.25 times the design pressure which is less than the plant piping design pressure consideration.
The pipeline may be above-ground with road and wadi crossings or completely buried.
Pipeline Stress Analysis Software
Pipeline stress analysis software is the same as plant piping stress analysis software as all those software have the provision for changing the design code and running the analysis. So all the below-mentioned software are used as popular pipeline stress analysis software
Caesar II by Hexagon
Auto-Pipe by Bentley
Start-Prof by PASS
Caepipe
Rohr II
Pipeline Stress Analysis Calculations
Pipeline Stress Analysis is performed for Sustained, Operating, Occasional, and Expansion Load Cases. The load cases are similar to plant piping analysis load cases. The main features for pipeline modeling are listed below:
Pipelines possess a very long radius (25 D to 60 D) elbows. So bend radius must be provided.
The buried depth of cover must be accurately entered into the soil parameters. Different pipeline segments normally have different buried depths as pipelines normally run on uneven surfaces.
If pipe sleeves are used in buried parts those have to be modeled as above-ground parts with spacer supports at even distances.
Normally expansion loops are provided at a distance of 500 m from the other expansion loop for above-ground pipelines.
Pipelines turn at various angles (not 45 degrees or 90 degrees similar to plant piping) so those need to be modeled correctly from pipeline GA drawing.
Pipeline models are created from Pipeline General Arrangement drawings or Route Plan Drawings (Refer to Fig 1 for a sample). Isometrics are not available similar to plant piping.
In most cases, the aboveground and buried pipeline design temperature is different and needs to enter correctly.
For buried parts of pipelines, proper soil data must be entered from soil reports by the civil team.
There are no Sh values similar to B31.3. A pipeline normally runs for several kilometers without any fittings attached. Because of such simplicity, the stress in the majority portion of a pipeline is quite predictable. Taking advantage of this characteristic, the code’s allowable stress for a pipeline is greatly increased, as compared to that for plant piping. All allowable values are linked with Sy (Specified Minimum Yield Strength) as the allowable stress of a pipeline is mainly to protect the pipe from gross deformation. Whenever you select B31.4 or B31.8 in Caesar II all Sh value fields become grey.
There is nothing like liberal stress in pipeline stress analysis.
Pipelines are always connected with piping systems. So in the same stress system, both piping and pipeline codes may be required to use.
The following figure shows a typical pipeline as modeled using pipeline stress analysis software Caesar II
Fig. 2: Pipeline Stress System in Caesar II
Pipeline Stress Analysis Basics
The basic equations for pipeline stress analysis are provided by the following codes and vary from one code to another. So readers are requested to refer to the following codes and standards for a better understanding of pipeline stress analysis basics.
ASME B31.4 for liquid and slurry pipeline stress analysis
Eliminates fouling problems due to oil ingress in process streams
Less gas loss
The dry gas seal advantages significantly outweigh the seal oil benefits
Process Calculations
Settle out Calculations
Blowdown calculation
Pipe sizing calculations
Hydrate calculations
Settle out calculation
Equalized pressure during a compressor shutdown.
High-pressure trip conditions are taken as pressures before settling out.
Enthalpy balance of the system.
It can be done using a spreadsheet or HYSYS.
It can define the design pressure for some of the sections.
Blowdown calculation
Intent: Reduce the pressure of the equipment to 50% of the design pressure within 15 minutes during a fire emergency.
Typically done using Dynamic depressurizing Utility in HYSYS
Relief valves are not depressurization devices.
Ball valve + Orifice combination OR control valve
The blowdown calculation takes the following into account:
Vaporization of liquid due to pressure reduction,
Vaporization due to heat input from the external fire,
Pressure after 15 minutes is reduced from design pressure to 50% of design pressure,
Start at settle-out conditions.
The gas compressor system is blocked in and no additional mass is fed into the system during blowdown.
Maximum allowable depressurization rate for the compressor O-rings of 20 bar/min,
There is no other heat input into the system other than fire.
The relief rate calculated is not limited by the flare.
Use to find the lowest temperature attained and hydrate formation possibilities.
Uncontrolled vs. Staged Blowdown
Fig. 3: Uncontrolled vs. Staged Blowdown
Pipe sizing calculations
Importance of pressure drop and machine performance.
Tools used.
Cooler header sizing.
Avoiding loops in suction.
Provision of drain boots.
Hydrate calculations
Hydrates are ice-like non-stoichiometric crystal structures composed of water molecules engaging natural gas molecules.
The solid formation chokes piping.
Flow problems.
The formation depends on P, and T conditions and composition.
Predicted by HYSYS.
Gas Blow-by calculations
Caused by losing liquid level in the scrubbers.
High-pressure gas flows into the low-pressure system potentially overpressurizing it.
Calculations are done to ensure that the downstream system is adequately protected.
The control valve is considered to be fully open during this case.
The highest operating pressure of the upstream system is considered for sizing.
Scrubbers
Vertical Knock out vessels.
Limit liquid carries over to the compressors.
Internals – SMS / SV / SVS
Air Coolers
Heat duty based on Process Simulation.
Process parameters based on the simulation.
The vendor does the sizing with HTRI or other proprietary software.
Pressure drop is critical.
Flare and Blowdown system
The flare system needs to be designed for
Blowdown depressurizing load.
Flaring due to compressor trip
Fire case relief
Blocked discharge of the compressor
The flare system may require a KOD based on the quality of the gas flared. (Liquid presence)
Control Philosophy
Capacity control
Antisurge control
Scrubber level control
Safeguarding philosophy
Process shutdown.
Emergency shutdown.
Other shutdowns.
Process shutdown
Close the discharge ESD valve. The suction ESD valve shall remain in an open position. The blowdown ESD valve shall remain in a closed position. The antisurge valves and capacity control valve goes to the open position. The motor stops and the compressor settles out to suction pressure. The auxiliaries keep running.
Generally initiated on trips on process parameters.
PSD1 shall Trip the compressor motor & auxiliaries, and Close the ESD valve on the suction and discharge header.
The antisurge valves and capacity control valve goes to the open position.
The external seal gas supply shall be isolated by the ESD valve on the seal gas line.
The compressor blowdown valves shall open and depressurize the gas to flare.
Initiated on Fire, Station ESD.
Other shutdowns
The suction, inter-stage(s), and discharge scrubbers low-level close liquid outlet ESD valves.
The inter-stage(s) and After-cooler fan high vibration shall trip the respective fan.
Low temperature at the aftercooler outlet shall trip the first working fan at 30 deg C and the next at 20 deg C.
External seal gas high pressure downstream of external seal gas pressure letdown valve for LP casing shall close the external seal gas supply ESD valve.
Cross Country Pipelines are very long-distance pipelines that run outside of the battery limit of the processing plants. The design of cross-country pipelines is governed by ASME B31.8 or ASME B31.4 for gas and liquid pipelines respectively. The pipeline material selection is a very important activity. The material selection of cross-country pipelines needs the overall knowledge of:
Design considerations.
Construction ease considerations.
operations and maintenance considerations.
hazards, risks, safety considerations and
overall economic considerations
Various codes and standards list the mandatory requirements during pipeline material selection but the final selection is optimized with user experience. The following paragraphs will list some important considerations for cross-country pipeline material selection.
Fig. 1: Typical cross-country Pipeline
Pipeline Material Selection Considerations
The following points need to be addressed while selecting cross-country pipeline materials
Development of plain carbon steel pipes to the high-end TMCP steel pipes:
Improved strength, both yield, and ultimate tensile strength
Improved toughness properties, i.e. the lowering of transition temperature from brittle to ductile fracture and an increase of the impact toughness.
Improved weldability.
Improved resistance towards hydrogen-related disintegration in sour service, i.e. due to exposure to a wet H2S-containing environment.
Increase
of yield strength and ultimate tensile strength by alloying:
Fig. 2: Alloying Elements for Pipeline Materials
Soil materials
It is primarily strength and friction properties that are a concern in pipe-soil interaction.
Classification of soil is based on a visual inspection and laboratory testing.
The aim of the investigation is to classify the soil so that strength parameters can be determined.
Cohesive soil consistency classification
Fig. 3: Cohesive Soil Consistency Classification
Non-cohesive soil characterization
Fig. 4: Non-Cohesive Soil Characteristics
ASTM D422-63 Standard test method for particle-size analysis of soils:
ρr = (emax − e)/(emax
− emin)
where
emax void ratio of the soil in its loosest state
e in situ void ratio
emin void ratio of the soil in its densest state.
Backfilling Material
Fertility of Agriculture fields
Sacrificial anodes
Sacrificial anodes are used for cathodic protection of the line pipe steel.
the traditional sacrificial anode materials for application are alloys based on zinc or aluminum, although other metals may be used (such as carbon steel to protect stainless steel line pipe).
Electrochemically the anode materials are characterized by the current capacity (measured in Ah/kg) and the closed-circuit potential (measured in V). Density (kg/m3) is the only relevant physical parameter.
Fig. 7: Typical material parameters for cross-country pipelines
Quality Management System
The manufacturing and QC departments operate on the most effective systems developed for the fabrication, material control, stage inspections, document, and data control. These systems follow some standards like ASME, API, etc, and comply with quality control.
The in-house team of Inspectors carries out visual, dimensional, and other stage inspections during fabrication, whereas NDT is given to a qualified NDT agency.
The Quality Control Manager reviews the qualification documents and past similar experiences record of authorized level II or level III NDT personnel.
Functions of the Quality control Department
The quality control department ensures the overall quality of the system. They are responsible for the following activities:
making the Inspection & test plans, according to the technical requirement and ensuring the implementation of these plans.
Ensuring the quality of material, workmanship, and welding procedures as per the governing codes and approved procedures.
During operation many times it happens that a piping system has to experience both hot and cold operating temperatures depending upon specific process requirements. In such situations, the piping must have to be insulated using both hot and cold insulation i.e dual insulation. But this requirement must have to be listed in the related P&ID, Line list, and Insulation Specification. Supporting the dual-insulated piping system is categorized into the following two cases.
1. Supporting hot and cold insulated pipe when pipe operating temperature is below 80 degrees centigrade.
Supporting dual-insulated piping is somewhat different from normal pipe support. Here I will describe the supporting philosophy for such a piping system when the pipe operating temperature is less than 80 degrees centigrade. When the pipe is having both positive(+) & negative(-) temperatures the hot insulation is applied first and cold insulation is applied on it to prevent heat gain from outside the pipe when the pipe is operating below zero degrees Centigrade.
When the pipe is operating in a negative temperature range then we have to prevent heat gain by a pipe through support from outside in that case we have to provide Cradle support. Note that High-Density-Urethane cradle support can sustain temperatures up to +80 degrees Centigrade after which the melting of the material starts.
For support please refer to the attached drawing. Follow the below-mentioned notes along with the figure.
Notes:
1. Cradle Radius (R) is based on insulation thickness (T1+T2)
2. Bottom of the Pipe shall be based on cradle thickness (T)
3. Temperature for HDPE cradle is less than +80 degree centigrade
2. Supporting hot and cold insulated pipe when pipe operating temperature is more than 80 degrees centigrade.
When the piping system faces a temperature of more than +80 deg. C which Polyurethane block cannot sustain, we have to think of some other arrangement of supporting which allows the higher operating temperature in both positive & negative ranges. If we use metallic shoe/base support in that case we have to protect cold insulation from higher temperatures due to its temperature limitations which can be done by carefully checking the temperature drop (Assume temperature drop or gain as 1.1-degree centigrade per mm of length) through the support or by extending the hot insulation layer along the shoe/base support up to extent of cold insulation temperature limitations. Refer to the attached figure to see the supporting philosophy for such cases. Follow the below-mentioned notes while reading the figure.
Notes for the figure:
1. Shoe width can be increased as per requirement.
2. While using one must check the temperature limitation of the cold support or cradle.
3. No damage to the cold insulation should be made while supporting.
Online Video Courses on Piping Support
To learn more about piping support design and engineering you can opt for the following video course.
The Rotary Selector Valve or RSV was developed in the early 1900s for use in irrigation systems. By the late 1940s, the product found favor in the growing oil and gas industry throughout Texas and California. The purpose of the unit was to manifold multiple wells into a single group flow line to feed various containment vessels or production facilities and maintain the ability to test single specific wells or sources on command.
Today the RSV is used widely throughout the oil and gas industry in addition to the chemical, refinery, water treatment, pulp and paper, cementing, food production, and general industry applications.
What is a Rotary Selector Valve or RSV?
The Rotary Selector Valve (RSV) which is also known as the Multiport Selector Valve (RSV), is a highly efficient fluid-control system used for allowing two-way diagnostic communication. It typically has eight-port valve that serves seven wells to a group port, such as a holding tank battery, while the remaining port can send product to another location like a testing lab. This allows in-line testing without requiring the remaining wells off line.
Rotary Selector Valve (RSV-Fig. 1) Components:
RSV Actuator
Heat Shield
Riser Kit
Thermal Coil
Thermal Blanket
Mounting Brackets
Lifting Pads
Applications:
A multiport valve can be used for fluid or gas systems
Multiple-port flow
Single port testing
Manual or automated operation
Water injection
Collection at the tank battery
Other-market application
The RSV supports the capability of diverting multiple inlet ports, allowing each port to flow uninterrupted into a single chamber known as the body of the valve and out through a single group outlet port. A rotor stem, positioned in the center of the bowl, allows for the selection of a single inlet source to be diverted through a 1.2D or 1.5D flow line elbow and out through a single test outlet port.
The valve position is controlled by manual or automatic operation. Manual operation requires placing an indexing wrench directly on the outer stem of the rotor and rotating to the selected stopping position. The automatic operation uses a hydraulic, pneumatic, or electrical controller that attaches directly to the outer stem of the rotor allowing for local or remote positioning of the rotor to a selected port.
Fig. 1: MSV
Advantages of Rotary Selector Valves
A rotary selector valve, also known as a rotary valve, is a type of valve used to control the flow of fluids or gases in a pipeline. It consists of a rotating cylinder that is divided into a series of compartments or ports. As the cylinder rotates, the ports align with the inlet and outlet ports, allowing the fluid or gas to flow through.
Rotary valves are commonly used in industrial applications, such as chemical and petrochemical processing, food and beverage production, and pharmaceutical manufacturing. They are preferred over other types of valves because they offer several advantages, including:
Low Maintenance: Rotary valves have a simple design and few moving parts, which makes them easy to maintain and repair.
High Durability: Rotary valves are made from materials that are resistant to corrosion and wear, which makes them durable and long-lasting.
Accurate Flow Control: Rotary valves offer precise control over the flow of fluids or gases, which makes them suitable for applications that require accurate dosing or metering.
Easy to Clean: Rotary valves are easy to clean and sterilize, which makes them suitable for use in sanitary applications.
Overall, rotary valves are a reliable and cost-effective way to control the flow of fluids or gases in industrial applications
Rotary Selector Valve Operation:
The RSV can be operated in a clockwise or counterclockwise direction.
As the rotor passes each port a spring-loaded wiper is engaged against the valve body to seal the seating surface. This creates a self-cleaning action and removes accumulated debris that might restrict proper operation. It also increases the life of the port seal and valve body.
An adjustable, spring-loaded Carbon Teflon Port Seal serves as a soft seal that prevents leakage at the test line and valve body junction. Back-up rings located on the port seal are designed to accommodate excess pressure, higher temperatures, or chemical presence.
Bidirectional Rotation
Self Cleaning
Self Sealing
Adjustable Sealing Surface
Back-Up Rings Improve Performance Life
Improved and Revised Metallurgy for Longer Life and Advanced Product Performance
Improved Elastomers and Seat Design to Meet Today’s Rugged Standards and Applications
Port Selection and Flow:
Fig. 2
The Port Seal can be adjusted with a specially designed tool. The tool has two retractable spring-loaded pins that engage and disengaged via a pistol grip trigger. Each pin fits into a slot located on either side of the adjusting nut.
Specially
designed O-Rings prevent external leakage through the valve body or head.
The downstream control valve can be remotely and automatically connected to the upstream setting point based on user requirements. The control system can be operated locally or remotely.
Optional quick
disconnect fittings at all inlet/outlet flanges allow simple removal or
relocation of the skid.
Special coatings
for offshore or extreme conditions.
DESIGN CRITERIA:
ASME B16.34 (American Society of Mechanical Engineers)
ASME Sec. VIII, Div. 1 / Div. 2 (FCI- Fluid Control Institute)
ASME B16.5 (FCC-Fluid Catalytic Cracking)
NACE MR 0175 / ISO 15156 (National Association of Corrosion Engineers)
API 598 (American Petroleum Institute)
ANSI/FCI 70-2-2006 (American National Standards Institute)
ANSYS finite element analysis software is employed for the main components of the RSV. Working and test conditions are analyzed and utilization factors (safety factors) to code allowable are verified.
A standard approach is to utilize the ASME VIII Division 1 design criteria and always employ the casting quality factor unless the design is unique, limited in quantity, and customized for specific applications.
Improvements to the RSV continue as the needs of the client base require with respect to metallurgy, flow, line-pigging characteristics, valve size, pressure classes, seals, differentials, controllers, communication protocols, and serviceability, metering capabilities, spill prevention or containment.
Additionally, we are faced with the task of ensuring each design supports ergonomic operation, safety, simplified integration, and environmental protection from leakages, such as H²S fluids or gas.
Simplified Design – 3 Main Parts:
Fig. 3
Skid Design:
Based on the results of the analysis conducted using FEA, the Sled meets the requirements of AISC with a safety factor greater than 1.5 for all loading conditions and a safety factor greater than 3 for the Lifting Eyes.
The multiport modular skid system utilizes a simple, design that saves time, money, and human resources. The system accommodates quick connect expandability for future field growth or quick disconnect to move those resources to other areas for improved utilization.
New Designs Based On Customer Requirements:
ANSI CL 1500 – 2500
SAG-D – Extreme Temperature
Full Body Alloy
Custom Skid – GA/Design
Fig. 4
RSV SKIDS WITH A SINGLE FLOW METER:
Fig. 5
Multi-Phase Flow Meter (MPFM)
A multiphase flowmeter is a device used in the oil and gas industry to measure the flow rates of a mixture of oil, gas, and water in pipelines. As the name suggests, it can measure multiple phases of a fluid flow simultaneously, which is important because, in many applications, the fluid stream is not homogeneous and can contain different types of fluids.
A multiphase flowmeter typically uses a combination of different technologies to measure the different phases of the flow, such as ultrasonic sensors, gamma-ray detectors, and differential pressure sensors. These measurements are then combined to calculate the flow rates of the individual phases.
Multiphase flowmeters are especially useful in offshore oil and gas production, where it is difficult and expensive to separate the oil, gas, and water before they are transported to shore. By accurately measuring the multiphase flow, operators can optimize production, reduce costs, and ensure compliance with regulatory requirements.
How does a Multiphase Flowmeter work?
The permanent multiphase flow meter (MPFM) uses technology for continuous flow rate measurements. The Typical Multi-Phase Flow Meter operates equally well in both oil and dry gas environments, making it possible to monitor and test dry gas, condensate, and oil wells with a single meter.
Via a remote
data link to the multiphase meter, users can validate well data, perform
quality control, generate well test reports, analyze well data, diagnose
production, and interpret reservoir intervals. By eliminating the need for
separators and their associated support systems or controls, the system is
ideal for both Onshore and Offshore Applications, satellite, or unmanned
locations, including subsea installations.
Since the need for a separator has been eliminated, the requirements for space, load, and maintenance are reduced. Continuous, highly accurate flow rate measurements allow for quicker response time to production anomalies. The typical MPFM has limited or no moving parts and is essentially maintenance-free. Remote monitoring increases the safety of field personnel and allows for better utilization of human resources.
Multiphase flowmeters (MPFM) work by measuring the different phases of a fluid flow, typically a mixture of oil, gas, and water, using a combination of different sensors and technologies. Here is a general overview of how an MPFM works:
Sensor Configuration: An MPFM typically consists of a combination of sensors that are placed in the flowline, including gamma-ray densitometers, ultrasonic sensors, and pressure transducers. Each sensor measures a different property of the fluid, such as density, velocity, and pressure.
Data Acquisition: The sensors are connected to a data acquisition system that collects the data from each sensor and processes it in real time.
Multiphase Flow Model: The data is then fed into a multiphase flow model, which uses algorithms and mathematical models to calculate the flow rates and properties of each phase of the fluid.
Output: The output from the MPFM can be displayed on a control panel or sent to a computer for further analysis. The information can be used to monitor the flow rates, the ratio of oil, gas, and water, and other important parameters.
Overall, the MPFM provides an accurate and reliable way to measure the flow of multiphase fluids, which is essential for optimizing production, monitoring the performance of wells and pipelines, and ensuring compliance with regulatory requirements.
Applications of MPFM
Multiphase flowmeters (MPFM) have a wide range of applications in the oil and gas industry, particularly in the upstream sector where they are used for the well testing and production monitoring. Here are some of the main applications of MPFM:
Well Testing: MPFM is used during the initial phase of well testing to determine the flow rates and characteristics of the fluids produced from a well. This information is used to optimize the production and recovery of oil and gas from the reservoir.
Production Monitoring: MPFM is used to monitor the production of oil and gas wells over time. This information is used to optimize the production process and to identify problems such as sand production, scale buildup, and water breakthrough.
Allocation Measurement: MPFM is used to measure the amount of oil, gas, and water produced from individual wells or fields. This information is used to allocate the production between different partners or to determine the royalties owed to the government.
Pipeline Monitoring: MPFM is used to monitor the flow of oil and gas through pipelines. This information is used to optimize pipeline operation and to identify problems such as pipeline corrosion, blockages, and leaks.
Reservoir Management: MPFM is used to monitor the behavior of reservoirs over time. This information is used to optimize the production process and to identify opportunities for enhanced oil recovery.
Overall, MPFM is a key technology in the oil and gas industry, allowing operators to accurately measure the flow of multiphase fluids and optimize production while minimizing costs and environmental impact.
Types of Multiphase Flowmeters
There are several types of multiphase flowmeters (MPFM) available in the market, each using different technologies and methods for measuring the flow rates of a multiphase fluid. Here are some of the most common types of MPFM:
Gamma Ray Densitometer (GRD): GRD uses gamma rays to measure the density of the fluid, which is then used to calculate the volumetric flow rate. This method is suitable for fluids with varying densities.
Venturi Meter: A Venturi meter is a type of differential pressure flowmeter that uses a constriction in the flowline to create a pressure drop. The difference in pressure is used to calculate the flow rate of the fluid. This method is suitable for low gas-liquid ratios.
Ultrasonic Flowmeter: An ultrasonic flowmeter uses sound waves to measure the velocity of the fluid. The transit time of the sound waves is used to calculate the flow rate of the fluid. This method is suitable for low liquid-liquid ratios.
Coriolis Flowmeter: A Coriolis flowmeter measures the mass flow rate of the fluid by detecting the Coriolis force that is generated by the fluid as it flows through a vibrating tube. This method is suitable for fluids with varying densities and viscosities.
Magnetic Flowmeter: A magnetic flowmeter measures the volume flow rate of a conductive fluid by inducing a magnetic field in the flowline and measuring the voltage generated by the flow of the fluid. This method is suitable for fluids with low conductivity.
Phase Doppler Anemometry (PDA): PDA is a laser-based method that measures the velocity of particles in the fluid flow. The velocity data is used to determine the flow rate and the size distribution of the particles in the fluid.
Overall, the choice of MPFM depends on the characteristics of the fluid being measured and the specific application requirements.
Multiphase Flow Meter Manufacturers
There are several reputed manufacturers of multiphase flowmeters (MPFM) in the market. Here are some of the top manufacturers:
Emerson Electric Co.: Emerson Electric Co. is a global technology company that offers a range of MPFM products, including Coriolis, ultrasonic, and gamma-ray densitometer flowmeters.
Schlumberger Limited: Schlumberger Limited is a leading oilfield services company that offers a range of MPFM products, including ultrasonic and gamma-ray densitometer flowmeters.
Weatherford International plc: Weatherford International plc is a multinational oilfield service company that offers a range of MPFM products, including ultrasonic and gamma-ray densitometer flowmeters.
ABB Ltd.: ABB Ltd. is a Swiss multinational company that offers a range of MPFM products, including Coriolis, ultrasonic, and magnetic flowmeters.
TechnipFMC plc: TechnipFMC plc is a global engineering and construction company that offers a range of MPFM products, including ultrasonic and gamma-ray densitometer flowmeters.
Krohne AG: Krohne AG is a German company that offers a range of MPFM products, including Coriolis, ultrasonic, and magnetic flowmeters.
Cameron International Corporation: Cameron International Corporation is a leading manufacturer of flow equipment, including MPFM products such as gamma-ray densitometer flowmeters.
These manufacturers have a long-standing reputation for quality and reliability and are widely used by the oil and gas industry for various applications.
Flow Characteristics:
The RSV can be operated in a clockwise or counterclockwise direction.
As the rotor passes each port a spring-loaded wiper is engaged against the valve body to seal the seating surface. This creates a self-cleaning action and removes accumulated debris that might restrict proper operation. It also increases the life of the port seal and valve body.
An adjustable, spring-loaded Carbon Teflon Port Seal serves as a soft seal that prevents leakage at the test line and valve body junction. Back-up rings located on the port seal are designed to accommodate excess pressure, higher temperatures, or chemical presence.
The RSV Multiport Skid provides a simple, cost-effective solution to manifold fluids in low maintenance, environmentally friendly package. The compact design reduces capital costs and allows for better utilization of resources when and where they are needed. The latest data communication technologies provide continuous feedback to help maintain a high level of operational efficiency and ensure quicker response time to production anomalies.
Process Engineering Deliverables for EPC of Oil and Gas Industries
Process Engineering Department is the main driver of any EPC Engineering Group. Because they provide information related to the actual process of what is going to happen. Other downstream departments use the information provided by the Process department in their design. The Process Department of any EPC organization normally generates the below-listed deliverables:
Process Engineering Deliverables
Process Engineering deliverables can be grouped into the following two classes:
Process engineering Documents, and
Process Engineering Drawings
Process Engineering Documents
The following deliverables come under the process engineering documents
