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A Guide to Plant Clearances and Access Requirements

Providing adequate clearances and access to process equipment, valves, and instruments are of utmost importance for the proper maintenance, operation, and safety of any plant. This present article can be used as a guideline for the preparation of plot plans and equipment layouts for various process plants, offsite, and utilities. This article covers general requirements for on-shore plant layout of process units, equipment, and general facilities, utility plant, and offsite areas. It gives basic considerations for plant clearances and access, equipment elevation, paving, grading, sewers, and other related items.

Plant Clearances and access for the operation and maintenance of proprietary equipment shall be in accordance with the manufacturer’s or equipment vendor’s drawings/operating guidelines or manual.

Considerations during Plant Layout Design

While designing the plant layout, the following guidelines need to be considered.

  • Process units and other facilities shall be integrated within a common plant area only where independent operation and shutdown for planned maintenance of different facilities are not required.
  • Where the process units and other facilities need to be separated from each other from an operations and maintenance point of view, they shall be located at sufficient distances apart from each other with separating spaces or roads. These shall be interconnected by pipe racks/pipe sleepers. It shall be noted that most of the time, these separating distances are governed by statutory / insurance rules.
  • Layout and design shall be based on, and provide access for, maximum use of specific mobile equipment for normal planned maintenance work.
  • Access ways for mobile handling equipment shall be normally 6m wide with 6m overhead clearance. Overhead clearances shall be finalized only after ascertaining the type of mobile equipment proposed to be used in the plant.
  • Where inaccessible to mobile maintenance equipment, facilities such as davits and trolley beams shall be provided. Proper passages shall be planned for the movement of equipment to the workshop for carrying out repairs and for the provision of maintenance space.
  • The plant layouts shall take into account the requirement of turning radii of mobile equipment and tanker lorries etc. Road-turning radii shall be suitable for the movement of proposed mobile equipment and tanker, lorries on the plant roads.
  • It is essential that the layouts meet statutory and insurance requirements as well as other requirements noted therein.
Plant Layout Design
Typical Plant Layout Design

Plant Clearance and Access Consideration for proper Accessibility

Proper Access shall be provided to equipment, valves, and instruments requiring operational control or normal maintenance during plant operation, by operating passages or elevated walkways, platforms, and permanent ladders.

  • Main operating or service levels are defined, as those areas during plant operation requiring plant personnel to be normally or intermittently present for substantial periods of time.
  • Stairways shall be provided as a primary means of access to main operating or service levels in structures, buildings, or furnaces. Cage ladders are not acceptable as the primary means of access.
  • Storage tanks shall also be provided with stairways where tank heights are more than approximate­ly 6 m. It is preferred to provide independent staircases for lined storage tanks.
  • Auxiliary service platforms are defined as those areas which, during plant operation do not require the presence of plant personnel except for short periods of time.
  • Primary access to platforms attached to vessels, auxiliary service platforms in structures, furnaces, and storage tanks for platforms up to approximately 6 m (20 ft) high, shall be by vertical cage ladders.
  • Auxiliary exists from platforms shall be by means of ladders. Such exists shall be required when platforms are longer than 7.5 m and shall be located so that no point on an operating platform is horizontally more than 22.5 m from a primary or auxiliary exit. The dead-end length of a platform shall not be greater than 7.5 m.
  • The vertical rise of any stairway shall not exceed 4.5 m in a single flight at a maximum angle of 40° and shall provide a minimum clear headroom of 2.1 m.
  • The vertical rise of ladders shall not exceed 5 m for a single run. Ladders that are located or extended more than 2.25 m above grade shall be provided with safety cages. Ladders that rise more than 5 m shall have an intermediate rest platform.

For equipment requiring operational control or normal maintenance during plant operation:-

Platforms or ladder access not less than those specified herein shall be furnished for equipment, locat­ed more than 3.6 m above grade and 2.1 m above another platform and include the following means of access:

  1. Where regular access is required, a minimum clear aisle width of 0.75 m and overhead clearance of 2.3 m shall be provided.
  2. Groups of valves at battery limits in elevated pipe racks and grade pipe sleepers shall be provided with permanent platform access. The type of valves (gate, plug, ball, etc.) shall be taken into account when locating such platforms.

Exceptions: Flanged nozzles on vessels, block valves in pipe racks (not requiring operation except for infrequent isolation) metal temperature measuring points in piping, and orifice flanges in lower pipe racks shall NOT be provided with permanent means of access.

Elevated platforms shall have sufficient space as defined herein for maintaining equipment; tall columns shall be provided with davits for removing covers, relief valves, blinds, etc. and the same shall be located such that these can be lowered safely to ground level.

Plant Layout Design Rules for Manual operation of valves

Valves requiring operation during plant operation or in an emergency shall be located as follows, otherwise, such valves shall be equipped with chain operators or extension stems:

  • Horizontally installed valves 6″ (150 mm) and smaller – the bottom of the handwheel shall not be higher than 2.25 m or the maximum height to the centerline of the handwheel shall be 2.3 m above grade or platform, whichever governs.
  • Horizontally installed valves 8″ (200 mm) and larger – maximum height to the centerline of the handwheel shall be 1.95m.
  • The preferred height to the centerline of all valves shall be 1.5 m above grade or platform.
  • Horizontally installed wrench-operated plug, ball, or butterfly valves shall be positioned so that the wrench movement arc is no higher than 2.3 m above the grade or platform.

Equipment Clearance and Access Guidelines

Layout and Safety Design Rules for Furnaces and Fired Heaters

  • Several furnaces in the same or different services and part of the same process unit or facility, together with associated close-coupled equipment, may be located in a single area and shall be segre­gated within that area only as required for operational and maintenance requirements.
  • To avoid a hazard, a furnace and close coupled equipment or a furnace area shall be located not less than 15m and preferably upwind (prevailing) from other equipment containing flammable flu­ids, except as follows :
    • The distance shall be measured from the outside of the nearest of furnace walls to the nearest point of the equipment considered.
    • Not less than 15 m from air coolers, containing flammable fluids.
    • Gas or liquid reforming furnaces, as used in ammonia and similar plants, may be located at a minimum distance from associated process equipment consistent with operating design and maintenance requirements.
  • Reforming and desulphurizing furnaces may be located at a minimum distance from their reac­tors and feed/effluent exchangers, consistent with operating and maintenance requirements.
  • Not less than 15m from switch rooms, un-pressurized control houses, and the compressor or pump house containing equipment in hydrocarbon service. These distance requirements shall generally be governed by statutory / TAC regulations.
  • Furnaces shall be located at a maximum practical distance from process equipment containing liquefied petroleum gas or similar materials in accordance with applicable Tariff Advi­sory Committee (TAC) rules with a minimum distance of 15 m.
  • Integral-type fired heaters such as start-up heaters shall be considered exceptions.
  • Fired furnaces of the following types that are used only for planned intermittent and start-up service may be located at a minimum practical distance from the equipment which they serve and not less than 6 m from other equipment, including air coolers containing flammable fluids.
    • Furnaces having welded coils and no header boxes.
    • Furnaces with header boxes facing away from other equipment.
    • Vertical cylindrical furnaces.
  • Areas for tube pulling shall be as shown on the plot plan and may extend over roads that are periph­eral to the unit and not required for access to other plot areas.
  • Furnaces shall be provided with platforms for operation and access as follows:-
    • Platforms for maintenance of soot blowers and dampers.
    • Platforms for burner operation when inaccessible from grade or in accordance with client requirements.
  • Platforms for access / observation doors except that when the doors are located less than 3.6 m above grade or another platform, access shall be by ladder only.
    • Platforms for header boxes containing removable plug fittings.
    • Platforms for decoking / swing elbow connections.

Plant Clearance and Access Considerations for Heat Exchangers, Air Coolers & Cooling Towers

Shell and tube heat exchangers at grade shall generally not be stacked more than two units high, with a maximum bundle weight of ten tonnes.

Permanent steel or reinforced concrete structures with monorail beams shall be provided for supporting bundles during pulling and lowering to grade if any of the following conditions apply :

  • When specified available mobile equipment is not suitable.
  • Shells stacked more than two units high.

For Shell centreline, more than 3.6 m above grade and Bundle weight exceeds ten tonnes

  • Platforms shall only be supplied where required for operation.
  • Although platforms shall not be provided for access to exchanger’s heads, the layout shall be arranged to facilitate maintenance.
  • Bundle removal of elevated air coolers may be over adjacent equipment where suitable cranes are available, otherwise, crane accessways shall be provided for removing bundles.
  • Access shall be provided for the maintenance of fan drives and headers as appropriate.
  • Proprietary plate type, double pipe, or multiple heat exchangers installed at grade will not be provided with handling or tube pulling facilities.

Air-cooled exchangers may be located at a grade above other equipment or structures, or above overhead pipe racks, subject to the effects of other equipment or structures on air cooler performance and as stated in the below paragraph

Air-cooled exchangers containing flammable fluids shall NOT be installed directly above control rooms, MCC rooms, transformers, and other major switchgear.

Water sprays shall be provided over equipment in the following services located directly beneath air-cooled air exchangers containing flammable fluids.

  1. Pumps handling flammable fluids with an operating temperature above the auto-ignition temperature or 260°C (560°F) whichever is less or,
  2. Pumps handling light hydrocarbons with a vapor pressure greater than 3.5 kg/cm² at 38°C (100°F) or with a discharge pressure in excess of 35 kg/cm² or
  3. Compressors in flammable vapor service.

Equipment adjacent to cooling towers should be located at a sufficient distance downwind as determined by each season’s prevailing winds from cooling towers, to minimize detrimental effects during fog-creating seasons.

The location of cooling towers with respect to roads should be considered carefully as the fog created under certain conditions of temperature and humidity presents a serious driving hazard. If necessary, roads should be provided on both sides of critically located cooling towers; public highways should be located at min. 45 m from cooling towers.

Reactors, Towers, and Vessels: Monorail beams shall be provided for charging reactors only when the use of a crane is not feasible.

Design Rules for Structure Clearance and Access

  1. Ladders shall generally be arranged for the side exit. Step-through ladders may be used for runs from grade up to a height of approximately 6 m or for elevated runs of approximately 3 m.
  2. Where ladders are not provided for access between platforms, intermediate steps shall be provided where the difference in elevation is more than 0.35 m.
  3. Handrailing shall enclose all stairways and platform areas where the clearance between the equipment and the edges of flooring is greater than 0.3 m. Toe plates only shall be provided around floor openings for permanent equipment where the clearance to the edge of the flooring is greater than 50 mm but less than 0.3 m. Handrails shall be provided at the periphery of tank roofs adjacent to access stairways and dip hatches.
  4. Sheds for pumps, compressors, and other equipment, if provided, shall be as follows.
  5. Where compressor sheds (or utility sheds) are provided they shall be open-sided steel frame structures, sheeted from roof eaves level down to a maximum height of 2.45 m above the compressor house floor level, with ventilation by means of natural draught.
  6. Where pump or equipment sheds are provided they shall be steel framed with sheeting as described in (a) above.

Compressor houses shall be provided with suitable facilities for handling the heaviest machine component during normal maintenance including the following (but excluding motor drivers):-

  1. A laydown area and suitable road access for this area shall be provided adjacent to the compressor house.
  2. The compressor house ground floor shall be designed to carry the internal parts of the machines, but not the top halves of casings, during maintenance.

The design of structures containing equipment shall not provide for the removal of equipment, not cons­idered a normal maintenance requirement, except as follows :

  1. To provide access to mobile equipment.
  2. To provide clearance within the structure
  3. To provide for the removal of sections of the structure where specified.
  4. Facilities for breakdown maintenance of vital equipment, the failure of which would seriously affect plant certification and/or production, e.g. Standby Generators / Power units.

Layout rules for Pumps and Compressors

Where permitted by the equipment design, the provision shall be made to allow the removal of the pump internals or driver without dismantling the piping or removing the isolation valves. For this purpose, a flanged spool piece or strainer on the pump nozzle shall be considered satisfactory.

  1. Pump isolation valves shall be located in the pump area as close as feasible to the pump and operable from grade. Valve hand wheels shall be oriented to leave clearance over a pump for maintena­nce and to permit operation without leaning over the pump.
  2. Pump / Compressor isolation valves shall be located near the equipment in such a fashion that no excessive loads are transferred to the Pump / Compressor nozzles.

In general, the drive ends of groups of similar pumps in process and utility plant areas shall line up. In offsite areas, the pump ends of the plinths of groups of pumps shall line up. Large pumps may be orientated parallel to a pipe rack or passage.

The alignment bellows for pumps shall not be mounted directly on pump nozzles. A flanged spool piece of sufficient length shall be installed and anchored between pump nozzles and the bellows.

Clearance and Spacing Rules for Buildings

Where practicable, central control rooms, MCC rooms, and substations shall serve several process units, utility plant, and offsite facility areas. Suitable isolation of utility supply shall be provided where required.

However, where impracticable, or as per the client’s operating philosophy, separate control/MCC rooms may be provided for utility and offsite areas.

Control rooms and switch rooms shall be located as follows:-

  • In an area which shall be at a safe distance from the nearest normal source of flammable hazard (Safe distance as per statutory or TAC rules) or,
  • When not located in a safe area shall be of pressurized design with the top of the air intake stack located in a safe area. In such cases, the construction may have to be blast-proof.

Design rules for Piping

  1. In general, process lines, utility headers, and instrument and electrical cables in process and utility plant areas shall be routed on overhead pipe racks at established elevations and in offsite areas on pipe sleepers at grade level.
  2. In general, lines to equipment in process and utility plant areas will be run overhead of maintenance and operating passages. However, short runs of pump suction and similar lines may be run at grade level where they do not obstruct maintenance access. Where the crossing of general walk­ways is unavoidable, walkover platforms shall be provided.
  3. Offsite pipe racks/sleepers shall normally be located adjacent to storage tank dykes and roads.
  4. Within dyked areas, lines shall be run by the most direct route, as limited by flexibility and tank settlement. Lines at grade serving tanks in a dyked area shall not pass through adjoining dyked areas.

Insulated lines passing through dykes shall be enclosed in sealed sleeves, and uninsulated lines shall be coated and wrapped. Insulated lines under road crossings, and all pressure lines beneath rail­road crossings, shall be enclosed in sleeves unless they are run in culverts.

When located below grade, piping provided with protective heating and piping and services requiring inspection and servicing shall be in built-up trenches.

Cooling, potable, fire service, and similar water piping, shall generally be buried with the centerline of the pipe below the frost line, or be provided with means to prevent freezing.

Buried piping shall be provided with a protective covering of at least 0.3 m.  In cases where heavy load traffic is expected, the minimum coverage may be 1.0 m with/without higher than the normal thickness of piping.

  1. At all changes in direction piping requiring frequent (at least once a week) cleaning shall be provided with flanged fittings or with five diameters (minimum) bends. The run of pipe between flanged cleanout points shall be limited to 12 m for cleaning from one end, and 24 m for cleaning from both ends.
  2. Lines that require occasional cleaning shall be provided with sufficient breakout flanges for disman­tling.
  3. Piping from pressure-relieving devices such as safety valves that discharge to a closed system shall generally be arranged to drain to headers without pocketing of lines and accumulation of condensates at the safety valves.
  4. The flare headers outside process unit areas shall be elevated and self-draining to the flare knockout drum. Flare auxiliaries, such as the ignitor station and steam injection control valve, shall be located near the drum. The line between the flare and the drum shall drain to the drum.
  5. Where practicable piping shall be designed to accommodate expansion without using such devices, such as expansion bellows, cold springing, etc. Line spacing may be based on anticipated line movements under normal operating conditions, if practicable.

Rules regarding Height for Atmospheric Discharge

  1. The top of stacks and continuously operating vents discharging hazardous vapors shall be at least 3 m above any platform or flat building roof, within a horizontal radius of 21 m from the stack or vent. This vertical clearance may be reduced by the same distance that a platform or building roof exceeds 21 m. However, the height shall be governed by State Pollution Control Board regulations and the HAZOP/hazard studies.
  2. The top of the outlet piping from relief valves and intermittent vents discharging hazardous vapors to the atmosphere shall be at least 3 m above any platform of a flat building roof within a radius of 15 m. This vertical clearance may be reduced by the same distance that a platform or roof exceeds is 15 m from the outlet piping.
  3. The discharge of steam, air, or similar non-flammable vapors from relief valves and continuously operating vents, shall be located to prevent any hazard to personnel.
  4. Minor vents, controlled by an operator, may discharge to the atmosphere local to the equipment vented subject to restrictions as noted above.

Guidelines for Flares

The location of flares shall be determined in accordance with client requirements, and vendor recommendations and in reference to the limitations of the ‘Guide for Pressure Relief and Depressurising Systems’ – API – RP.521.

  1. It is desirable that the flare shall be positioned upwind of process units and tankages, to reduce risks of ignition of possible vapor leaks.
  2. The safety zone around the flare stack shall be decided based on an acceptable radiation level at grade. This zone shall be isolated by means of a fence.

Design Rules for Maintenance and Equipment Handling

  1. Handling facilities shall be limited to the handling of working parts of equipment that require frequent or routine service and which are inaccessible to the handling facilities assumed to be available at the plant. Such facilities shall not be designed to handle heavy parts which normally are unaffected, such as the bedplates of rotating machines, rotating equipment, the bodies of compressors, machinery, frames, etc.
  2. Special consideration must be made where major machines are involved (e.g. multi-case compressor trains) where heavy lifts are likely and laydown areas are required. Clear passages to workers are also required in such cases.
  3. The design and installation of monorail beams, overhead traveling cranes, and hoist trestles shall be based on lifting the parts to be handled and transporting them or lowering them to specified maintenance areas or to grade. From these points, they are expected to be removed by skids or hand trucks to other areas which are more suitable for maintenance.

Requirements for Paving, Surfacing, and Grading

Paving shall be provided as shown on the plot plan. Walkways to buildings only and the following areas shall be paved subject to client’s discussions, on a contract-to-contract basis.

  • The areas below bottom oil-fired or combustible liquid-containing furnaces and under elevated structures support coke drums or catalyst-containing vessels.
  • The areas around groups of two or more pumps are located outdoors, extending approximately 1.2 m beyond the pump foundations with bunds on all sides.
  • The areas around process equipment :
    • Drainage facilities shall be provided to recover spilled materials or drain to the chemical/effluent system.
  • The areas around rail and road loading installations, additive and metering facilities, extending approximately 1.2 m around the facility with bund on all sides.
  • Areas below pressurized spheres and bullets.
    • Curbs, when required to retain spilled materials, shall normally extend from the bottom of the paving to a height sufficient to contain the full contents of the largest atmospheric tank in the area. Concrete surfaces normally exposed to acids or similar corrosive materials shall be provided with protective coatings such as acid/alkali-resistant tiling.
  • All paving shall be sloped towards drainage points, the minimum slope shall be 1 in 125 and the maximum fall shall be 150 mm, except for floors of control rooms, operator houses, and MCC room which shall be laid level. High points of paving shall generally be coincident with the finished floor elevation applicable to the area under consideration.
  • The type and surfacing of roads and access ways for maintenance vehicles access shall be as shown on the plot plan.
  • Unpaved areas within the battery limits of utility plant and process unit areas, administration and parking areas, shall be graded and surfaced with a minimum of 50 mm of gravel, crushed stone, or other suitable material.
  • Offsite areas such as tank farms inside bund walls, pipe racks, and areas alongside roads, will not normally be surfaced except where required for maintenance or as specified in statutory regula­tions.
  • Finished grade elevation of different plant areas or within the battery limits of an area, may be varied and established to permit adequate drainage.
  • Roads shall be ramped over piping at the intersection with grade-level pipe sleepers, if possible. If not, suitable culverts shall be provided for the passage of pipes.

Design Considerations for Pipe Trenches and Pits

  • In general, pipe trenches shall have concrete or brick side walls, open tops covered with grating or plate, and bottoms surfaced with crushed stone.
  • Paving with acid-resistant titles shall be furnished in acid or similar corrosive services, and shall be sloped for drainage, with a drainage sump at the lowest point.
  • The following items shall be considered :
    • Firestops shall be provided where trenches cross-unit battery limits, or to maintain separate areas, such as totally enclosed buildings, furnaces, or grouped equipment.
    • Pipe trenches located near fired heaters or any sources of ignition shall be backfilled with sand and be provided with sealed covers.
  • The minimum width of pipe trenches shall be 450 mm. A minimum clearance of 100 mm shall be provided between the outside of the pipe, flange or insulation, and walls, and 50 mm to the high point trenches bottoms.
  • Pipe trenches in paved areas shall be covered with plate or grating set flush with the top of the paving, and in unpaved areas shall be covered with a steel plate set 50 mm above the high point of adjacent grade. Trenches inside buildings shall be covered with MS / CI grating set flush with the floor. Trenches subject to vehicle traffic shall be provided with removable reinforced concrete covers set flush with the surface.
  • Where provided, pits shall have concrete/brick walls. Floor surfacing of pits shall be concrete. Pits shall have a sump for the collection of drainage.  The pit floor shall slope towards the sump.
  • Access to pits shall be by ladders or ladder rungs cast into the walls. Stairways shall be provided for pits containing equipment such as vessels, pumps, and exchangers. Auxiliary exit ladders shall be provided if any point on the pit floor is more than 7.5 m from a main or auxiliary exit.
  • Open pits shall be provided with handrailing and 150 mm high curbs above the grade level.
  • Closed pits shall be provided with suitable removable covers set flush with paving in paved areas or 50 mm above grade in unpaved areas. Sealed covers, with a vent, piped to a safe location shall be provided for pits located near fired furnaces or similar sources of ignition.

Few more resources for you…
Piping Design and Layout
Piping Stress Analysis
Piping Materials
Piping Interface

Further Studies

Major features of CAESAR II-2019, Version 11.00

The upcoming CAESAR II release will deliver a number of significant new and extended capabilities in response to current market requirements, as well as direct feedback from the growing CAESAR II user community. Currently, they are running their beta testing for the new version of the software. From that beta software, We come to know that The following changes will have been made to CAESAR II 2019, Version 11.00

Piping Input:

  • Added the CAESAR II Determines option to Allowable Stress Indicator for the B31.8 code, similar to the existing implementation for B31.4. CAESAR II Determines specifies that the software selects the stress equations based on the calculated axial load in the piping system.
  • Added node name and node number formatting options to Options > Node Numbers. You can now display names and numbers with the same formatting available for Options > Node Name in the Static Output Processor. 
  • Updated and renamed the Global Coordinates and Global commands to View/Set Coordinates. The new Global Coordinates dialog box displays a grid view of nodes and coordinates for all disconnected elements, and you can edit the values.
  • Updated the Coordinates and Elements lists to support the new View/Set Coordinates command. The start (From) node displays in the Node column of the Coordinates list. Right-click > View/Set Coordinates displays on the Coordinates list. Disconnected element rows highlight in green in both lists.
  • Extended the range for node numbers. A node number previously had a maximum value of 32,000. It now has a maximum value of 8,000,000. Refer Fig. 1
  • Improved the efficiency of processing disconnected segments to function with the extended node number range.
  • Improved the behavior of node names. The same node name now displays on all elements sharing the same node.
  • Increased the maximum length of node names from 10 to 25 characters.
  • Increased the number of Uniform Loads from three to nine vectors
  • Added a restraint legend which allows you to visually identify and edit restraint gap values.
  • Added the Rigid Type option to the Rigids auxiliary data tab. When you define a rigid type, the software graphically displays that type for the element in the model view.
  • For the ISO-14692 2005 code, allowed editing of the Pressure SIF box on the SIFs/Tees auxiliary tab. You can now change the value in both boxes from the default value of 1.3. 
  • Adjusted the density for material (191) A335 P91.
  • Added the ability to create multiple toolbar and command profiles. You can switch between profiles as needed. Delivered a new functional profile as the default profile.
First look of Caesar ii 2019 with increased node number option
Fig. 1: First look of Caesar ii 2019 with increased node number option

Load Case Editor:

  • Added import of a properly formatted Excel .xlsx file into the Static Analysis – Load Case Editor. The software also provides an example template file, LCE_Template.xltx, in the C:\\ProgramData\Intergraph CAS\CAESAR II\11.00\System\templates folder.
  • Added export of an Excel .xlsx file from the Static Analysis – Load Case Editor.
  • Added an Exclude option that allows you to easily remove a selected load case from the static analysis.
  • Updated the Static Analysis – Load Case Editor for the DNV 2017 piping code, including a new limit state (LMST) stress type for combined load cases, and a new Limit State Load Type field for non-combined load cases and non-LMST combined loads. 
  • For ASME NC-3658.3 flanged joint calculations, changed the hydrotest (HYD) load cases to use the same allowable as the occasional (OCC) load cases. 

Piping, Equipment, and Environmental Codes:

  • Added support for ASCE 7-2016 wind and seismic loads.
  • Added support for the China GB 50009-2012 wind code.
  • Added support for the ISO 14692 2017 piping code.
  • Added support for the DNV 2017 (DNVGL-ST-F101) piping code, including a new DNV/Offshore tab for Special Execution Parameters.
  • Updated the CODETI code to the November 2016 edition, and corrected CODETI code stress equations in the Quick Reference Guide.
  • Updated the KHK Seismic Design Guideline for the High-Pressure Gas Facilities to the 2012 edition.
  • Updated the ASME B31.1 code to the July 2018 edition.
  • Updated the BS EN 13480 code to the June 2017 edition.
  • Updated the Errors and Warnings grid to perform more like Microsoft Excel. The grid supports selection and copy of grid rows between the grid and Excel.
  • For the Seismic Wizard, changed the default value for the ASCE 7 Response Factor R from 12 to 3.5 to comply with ASME B31.
  • Added support for displaying all component stress values (hoop, allowable, SIF) in reports instead of only the highest component stress.

Material and Content:

  • Updated the Material Database Editor grid to support copy, cut, paste, and delete of cells and rows within the grid and between the grid and Excel.
  • Updated the hanger table for LISEGA.

Configuration:

  • Updated B31.4 and B31.8 codes to function similarly for non-default configuration settings and combination load cases.

Equipment:

  • Expanded the redesigned Equipment Manager to include API 617, API 560, API 661, NEMA SM23, and HEI Standard equipment modules into the single Equipment Manager window. (API 610 equipment was moved into the Equipment Manager in the previous release.) Changes include updates to calculations and updates to reports to meet Equipment Manager standards.
  • Added several usability improvements. Node Number is now optional. Most recently used files are now available. Status and warnings for the equipment input display before analysis and in the status pane and in the output report after analysis completes.

Analysis:

  • For static analysis, clarified the usage of the wind load reduction factor for ASCE 7. You must explicitly apply this factor to the wind load component in a wind load case. 
  • For dynamic analysis, corrected the determination of the pressure stiffening effect on bends by excluding hydro pressure.

User Interface:

  • Added shortcut keys that are used consistently throughout the software.
  • Improved the File tab options on the main window ribbon, including improved existing options, and new folder and help access.
  • Removed the secondary menu from the main window. All commands are on the main window ribbon.
  • Added a new Layout menu to the main window ribbon. The menu provides theme, language, and icon size options and allows you to reset to the default layout.
  • Changed the default look of the software to a new light gray Light theme. The existing dark gray Dark theme is available on the Layout menu.
  • Changed some graphics defaults to better match the most commonly-used settings. New defaults include: Default Operator (Select), Hide Overlapping Text (on), Text Options (12 pt. by default), and Bottom and Top background colors (white).
  • Updated the File > About window to improve usability and appearance. Also updated the Help and About icons to provide a look consistent with other interface improvements.
  • Updated the Help tab to eliminate unnecessary commands, better organize the remaining commands, and provide a new help search function. 

Isometrics:

  • Added the option to create .pdf files when you create .dwg files using Create Isometric Drawings. The software also saves .dwg drawing files and .pdf files in the same folder as the piping model.
  • Updated Generate Stress Isometrics to Personal ISOGEN 2016 (10.0.0.1) and to I-Configure 2016 (06.00.00.11).
  • Improved the creation of isometric drawings for models containing dummy legs.
  • Improved usability of stress isometric annotations. When you select a Restraint/Hanger Types or SIF/Fitting Data input feature, the software also selects the corresponding Node Numbers feature.

Underground Pipe Modeler:

  • Updated the Underground Pipe Modeler grid to support copy and paste of rows within the grid and between the grid and Excel.

Output Processor:

  • Added access to the Data Export Wizard from the Static Output Processor. 
  • Added a Maximize/Restore button to report windows for static reports. The software also saves the most recent window size and uses it when you open the next report window.
  • Changed standard reports to more consistently report component stresses. Created a standard Stresses report, a new Stresses (Multiple Code/Allow.) report for transportation and offshore codes. Changed the Stresses Extended report to the Stresses Extended (Legacy) report. Removed the previous Stress and Code Compliance reports. Renamed the Code Compliance Extended report to Code Compliance.

Configuration:

  • Updated B31.4 and B31.8 codes to function similarly for non-default configuration settings and combination load cases.

Material and Content:

  • Updated the Material Database Editor grid to support copy, cut, paste, and delete of cells and rows within the grid and between the grid and Excel.
  • Updated the hanger table for LISEGA.

External Interfaces:

  • Improved Import PCF to allow you to import a large number of files.
  • Added an interface for BOSfluids file import, using a dialog box similar to the other hydraulic module interfaces. Also added an option to directly open Dynamic Analysis after import completes.
  • Updated the neutral file format so that line numbers, line color, line visibility, and bend overlay thickness now import and export.
  • Improved the Data Export Wizard to allow multiple output report exports in one session. Improved defaults of the Input and Output Files window and changed the default output file format to .accdb (Microsoft Office 2007 and later Access database) to improve usability.

Documentation/Help:

  • Converted help to a new help viewer with an improved interface and search, and changed the format of units to eliminate display issues.
  • Updated thermal coefficient of expansion topics to specify the length and temperature units of the model.
  • Added more details and equations to the CAESAR II Determines option of Allowable Stress Indicator for finding the pipe restrained/unrestrained status in the B31.4 code.
  • Clarified usage of the Free Measure option of Distance. The option should only be used in 2D views.
  • Added a shortcut key overview to the Quick Reference Guide.
  • Added information on editing ASCII text files.
  • Clarified descriptions of numeric calculations in delta and length fields of Classic Piping Input.
  • Added descriptions for Multiple Load Case Hanger Design Options in the Hangers auxiliary panel, the Hanger Design Control Data dialog box of Classic Piping Input, and the Technical Discussions section.
  • Added a note to Type for SIFs & Tees that describes the importance of properly defining tees to avoid overly conservative SIF values.

Learn the changes in the different versions of Caesar II software:

Caesar II Version 12 vs Caesar II Version 11
Major features of CAESAR II-2019, Version 11.00
Added Features of CAESAR II 2018, Version 10.00
What’s New in CAESAR II, 2016 (Version 8.0)
Practical changes in Caesar II version 7.0 (2014) with respect to its earlier version.

Procedure for Converting a Higher version Caesar II file into its Lower version

Many a time during interfacing with other EPC organizations or vendors, Caesar II file transfer becomes a necessity to reduce re-modeling time. And most of the time it happens that the Caesar II versions do not match. The caesar files with the lower version (i.e., version 7.0) easily open in their higher version. But if the file received is of a higher version (i.e., version 8.0) then it’s difficult to open in the lower version. For opening such files into the lower version there is a trick. One has to follow the neutral file methodology for such activities. In this article, the procedure for opening a caesar II file version 8.0 into caesar II version 7.0 will be explained.

However, it’s not suggested to use a lower version of the software for a higher version file as due to changes in codes the results of both versions will be different. So the same situation must be handled with utmost care.

Neutral file Conversion

Ask the neutral file of the higher version from other contractor r vendors. The procedure for neutral file conversion is explained below in Fig. 1 and 2.

Procedure for making Neutral file from caesar II file
Fig. 1: Procedure for making Neutral file from caesar II file

The Caesar II neutral file will be created in the same folder where the original file is stored. Refer to Fig. 2 to know the generated Neutral file.

Neutral file in the same path of original file.
Fig. 2: Neutral file in the same path as the original file.

Neutral file to Caesar II file conversion

Once you possess the Neutral file of the higher version and saved it in some known path, Open the Caesar II lower version (7.0). In a similar way again go to Interfaces—-Caesar II neutral file—-Convert Neutral file to caesar II input file. And follow the steps mentioned in Fig. 3

Generation of Caesar II file from Neutral file.
Fig. 3: Generation of Caesar II file from Neutral file.

Now Caesar II file is ready to open in your version of the software. Note that the load cases you have to prepare them again.

The Caesar II version 2016 (8.0) file I could able to open in Version 2014 and Version 2013 R1 but it does not open on Version 2011 R1. It showed an error and the conversion could not succeed.

For some years, It was not possible to open upper-version C2 files into the lower versions. But again the feature is active in recent versions. Mostly after the completion of the Caesar II software takeover process by Hexagon, wherever a new version of Caesar II software is released by Hexagon their Caesar II files can be opened in the lower versions by following the above-mentioned method.

However, for opening a caesar file of version 12.0 into its lower version 11.0, neutral file conversion is not required. The caesar ii files of version 12 automatically open in caesar ii version 11 (2019).

Substantive Changes to 2014 Edition of ASME B31.3

Many of you are aware that the 2014 edition of ASME B 31.3 is scheduled to publish on 21st February 2015. Similar to every new edition this edition too contains several updates. Thanks to Mr. Don Frikken who has listed a few of the substantive changes in one of his blog posts. Here I am providing few major points. For details please read the complete article by clicking on the link provided at the bottom of this post.

In addition to the many clarifications, updated references to codes and standards, updates to basic allowable stresses, and added listed materials, there are several substantive changes to the 2014 Edition of ASME B31.3, Process Piping.

Some of these changes are listed below:

The definition of Category M Fluid Service is revised in the 2014 edition to provide better guidance on the selection of the Category M Fluid Service designation. As per the new edition of the code Category M Fluid Service is A fluid service in which all of the below-mentioned conditions apply:

  1. The fluid is so highly toxic that a single exposure to a very small quantity of the fluid caused by leakage, can produce serious irreversible harm to persons on breathing or bodily contact, even when prompt restorative measures are taken; and
  2. If after consideration of piping design, experience, service conditions, and location, the Owner determines that the requirements for Normal Fluid Service do not sufficiently provide the leak tightness required to protect personnel from exposure.

Flared laps are prohibited for use in Category M fluid service in the 2014 edition.

Because of the potential for misapplication of the alternative rules, and because many of the provisions of Appendix P had been incorporated into the base Code, Appendix P has been removed in the 2014 edition.

The 2014 edition explicitly requires that the maximum value of SL considering all conditions be used in calculating the allowable stress range.

The 2014 edition requires that thermo-wells need to comply with ASME PTC 19.3 TW.

The 2014 edition requires that when cold spring is used, the reactions be computed both with the assumption that only two-thirds of the design cold spring is present and with four-thirds of the design cold spring present.

The 2014 edition permits the hydro test pressure to be lowered to the design pressure while examining for leaks. The 2014 edition simplified the calculation of hydro test pressure.

The 2014 edition restricted the use of Fig. 323.2.2B to provide a further basis for the use of carbon steels without impact testing. The Code warns that the calculation of stresses due to cold springing or misalignment should be included as part of the stress ratio.

The 2014 edition added requirements for and illustrations of welds for integrally reinforced branch connections.

The 2014 edition revised the Preheat and Heat Treatment requirements somewhat. This revision, along with revisions to ASME B31.1, makes the preheat requirements in the two Codes the same.

The 2014 edition added specific examination personnel qualification requirements, which are those described in ASME B&PV Code, Section V.

The 2014 edition added specific acceptance criteria for magnetic particle and liquid penetrant examination.

The 2014 edition changed the leak test pressure from 1.5 times the design pressure corrected for temperature to 1.25 times the design pressure corrected for temperature.

Learn the code changes in different years:

What’s new in ASME B31.3-2020? ASME B31.3 2020 vs 2018
Changes in the 2018 Edition of ASME B31.3 2018 with respect to the 2016 edition.
14 major changes in ASME B 31.3-2016 with respect to its earlier edition (ASME B31.3-2014)
Substantive Changes to 2014 Edition of ASME B 31.3
Major Stress-related differences in Between 2012 edition and 2010 edition of ASME B31.3.

What is a Ball Valve? Parts, Types, Working, Materials, Testing, and More

In the world of piping engineering and fluid control systems, ball valves are a crucial component that plays a vital role in regulating the flow of liquids and gases. These valves are widely used in various industries, ranging from oil and gas to water treatment, due to their exceptional reliability, versatility, and ease of operation. This article provides everything you need to know from ball valve definition, types, parts, working, materials, end connections, specifications, advantages, and standards to testing and uses.

What is a Ball Valve?

A ball valve is a type of valve that uses a spherical perforated obstruction (a rotary ball) to stop and start the hydraulic flow. A ball valve is usually rotated 90° (quarter-turn valve) around its axis to open and close. It is one of the most widely used valve types. Ball Valves are suitable for both liquid and gas services. They are highly popular in the chemical, petrochemical, and oil and gas industry because of their long service life and reliable sealing throughout their service life. Ball valves can even be used for vacuum and cryogenic services. Developed around 1936, Ball valves are among the least expensive valves which are available in extremely wide size ranges.

Ball valves are sometimes used as control valves due to their cost-effectiveness but are not preferred as they don’t provide precise control and adjustments. The ball is positioned within a valve body, and a handle or actuator is used to rotate the ball either perpendicular or parallel to the flow direction, thus controlling the fluid flow. When the hole aligns with the flow direction, the valve is in the open position, allowing fluid to pass through. Conversely, rotating the ball to block the hole closes the valve, stopping the flow.

Applications of Ball Valves

Ball valves find application across a wide range of industries due to their versatility and ability to handle various types of fluids, from corrosive chemicals to high-pressure gases. Major applications of ball valves include

1. Use of Ball Valves in Refineries:

I have seen ball valves to be used as shut-off and isolation valves for tower bottom lines and thermal-cracking units; Gas/Oil separation lines, Gas distribution measuring, metering, and pressure regulation stations, Oil loading control stations, Pumping, and compressor stations, Emergency shut-down loops, Refining units, etc.

2. Use of Ball Valves in Chemical and Petrochemical Complexes:

Ball valves are used for low differential pressure control, emission control, and handling highly viscous fluids, and abrasive slurries in process and storage facilities. They are suitable for handling corrosive chemicals and hazardous materials, making them a preferred choice in chemical processing plants.

3. Power Industry Applications of Ball Valves:

For boiler feedwater control, such as burner trip valves, for control and shut-off for steam, etc.

4. Ball valves in Gas and Oil Production:

In subsea isolation and shut-down facilities, For oil-head isolation, pipeline surge control, processing separation, storage, transmission and distribution, secondary and enhanced oil recovery.

5. Use of ball valves in the Pulp and Paper Industry:

They are used as shut-off valves in pulp mill digesters, batch-digester blow service, liquor fill and circulation, lime mud flow control, dilution water control, etc.

6. Water Treatment:

Municipal water treatment plants utilize ball valves for controlling the flow of water in various processes, such as filtration, chlorination, and distribution.

7. HVAC Systems:

Heating, ventilation, and air conditioning systems use ball valves for regulating the flow of water and refrigerants in commercial and residential buildings.

8. Other uses of ball valves include

  • Food Industry
  • Marine and Solid transport
  • Water supply and transport
  • Manufacturing

Ball Valve Standards

Below-mentioned international Codes and Standards are used for Ball valve Design

  • Design Standard – API 6D / ISO 14313 / BS EN 17292/BS 5351/MSS SP 72
  • Testing Standard – API 6D / API 598 / BS 6755 Part I/MSS SP 61
  • Fire testing Standards – As per API 6FA, API 607, ISO 10497, or BS 6755 Part II.
  • Dimensional Standard – ASME B16.10 / API 6D

Parts of a Ball Valve

The housing, seats, ball, and lever for ball rotation are the major parts of a standard ball valve. Refer to Fig. 1 below which shows the internal parts of a ball valve.

Ball Valve Parts
Fig. 1: Ball Valve Parts

Ball valves are manufactured with the following crucial parts:

Valve Body:

The main part of a ball valve is the valve body which contains all of the internal components for on/off control.

Rotary Ball:

A ball with a center hole through which the media flows is the main characteristic of ball valves that differentiates these valves from other valve types. The hole of the ball through one axis connects the inlet to the outlet. The Stem controls the direction of the ball. The ball may be free-floating or trunnion-mounted. Trunnion-mounted ball valves reduce the operating torque to about 2/3rd that of the floating ball valves.

Stem:

The stem of a ball valve connects the ball to the external control mechanism.

Seats:

The seats of a ball valve are discs that lie in between the ball and the body. It provides the necessary seal between the two and also supports the ball.

Power Source:

A manual or actuated power source provides energy to the stem of the ball valve for rotating it. Manual actuation uses levers and handles, which the operator controls during requirements. Automatic actuators use electric, pneumatic, or hydraulic power sources.

Packing:

Packing is a seal around the stem to prevent the media escape.

Bonnet:

The bonnet is part of the ball valve body that contains the stem and packing.

The following video clearly shows the parts and working of ball valves using an animation.

Ball Valves: Parts and Working

Ball Valve Working Principle

A ball Valve is a rotary motion valve. When the stem (Item 04 in Fig. 1) transfers the motion to the connected ball (Item 03), the ball rotates. This ball of a ball valve is rested and supported by the ball valve seats (item 05). This rotation of the ball over valve seats allows the bore to open or close helping the fluid to flow or stop.

For manual ball valves with normal service, when the port opening of the ball is in line with the inlet and outlet ports, flow continues uninterrupted through the valve, undergoing a minimal pressure drop if a full-port ball is used. Obviously, the pressure drop increases with the use of a reduced-port ball. When the hand operator is placed parallel to the pipeline, the flow passages of the ball are in line with the flow passages of the body, allowing for full flow through the closure element. As the hand operator is turned to the closed position, the ball’s opening begins to move perpendicular to the flow stream with the edges of the port rotating through the seat. When the full quarter-turn is reached, the port is completely perpendicular to the flow stream, blocking the flow.

In throttling applications, where the ball is placed in a mid-turn position, the flow experiences a double pressure drop through the valve, similar to a plug valve. When a characterizable ball is used to provide a specific flow to position, as the ball is rotated from closed to open through the seat, a specific amount of port opening is exposed to the flow at a certain position, until 100 percent flow is reached at the full-open position.

As with all rotary-action valves, the ball valve strokes through a quarter-turn motion, with 0° as full-closed and 90° as full-open. The actuator can be built to provide this rotary motion, as is the case with a manual hand lever, or can transfer linear motion to rotary action using a linear actuator design with a transfer case.

When full-open, a full-port valve has minimal pressure loss and recovery as the flow moves through the valve. This is because the flow passageway is essentially the same diameter as the pipe inside diameter, and no restrictions, other than some geometrical variations at the orifices, are present to restrict the flow. The operation of throttling full-port valves should be understood as a two-stage pressure drop process. Because of the length of the bore through the ball, full-port valves have two orifices, one on the upstream side and the other on the downstream side. As the valve moves to a mid-stroke position, the flow moves through the first narrowed orifice, creating a pressure drop, and moves into the larger flow bore inside the ball where the pressure recovers to a certain extent. The flow then moves to the second orifice, where another pressure drop occurs, followed by another pressure recovery. This two-step process is beneficial in that lower process velocities are created by the dual pressure drops, which is important with slurry applications. The flow rate of a full-port valve is determined by the decreasing flow area of the ball’s hole as the valve moves through the quarter-turn motion, providing an inherent equal-percentage characteristic with a true circular opening. As the area of the flow passageway diminishes as the valve approaches closure, the sliding action of the ball against the seal creates a scissor-like shearing action. This action is ideal for slurries where long entrained fibers or particulates can be sheared off and separated at closing.

At the full-closed position, the entire face of the ball is fully exposed to the flow, as the flow hole is now perpendicular to the flow, preventing it from continuing past the ball.

With the characterized segmented ball design, only one pressure drop is taken through the valve—at the orifice where the seal and ball come in contact with each other. When the segmented ball is in the full-open position, the flow is restricted by the shape of the flow passageway. In essence, this creates a better throttling situation, since a pressure drop is taken through the reduction of flow area. As the segmented ball moves through the quarter-turn action, the shape of the V-notch or parabolic port changes with the stroke, providing the flow characteristic. Like the full-port design, the sliding seal of the characterizable ball provides a shearing action for separating slurries easily.

Ball Valve Types | Types of Ball Valves

Types of Ball valves are classified based on various parameters as listed below:

1. Ball Valve Types: Short Pattern vs. Long Pattern

Depending on the end-to-end dimension of the valves, two types of ball valves are available. They are

  • Short pattern ball valves, and
  • Long pattern ball valves

The end-to-end dimension and weight of short-pattern ball valves are less as compared to long-pattern ball valves. However, During piping design, a long pattern dimension is selected for ease of connection to pipe flanges. Also, short-pattern ball valves are not available after a specific size and flange rating. So, long pattern ball valves are the only option in such cases.

2. Types of Ball Valves: Soft Seated vs. Metal Seated

Depending on the seat materials of the valve, two types of ball valves are found; Soft Seated and Metal Seated Ball Valves.

Soft, non-metal seated ball valves satisfactorily cover most of the applications. Soft seated ball valves use a thermoplastic material such as PTFE, NBR, etc. However, abrasive media, high pressure, and temperature can severely stress the polymeric seals leading to damage. Because of this reason metal-seated ball valves were developed in the 1960s.

Metal seated ball valves use metal as seat material such as 316 SS, Monel, etc. Tight shut-off, no jamming, smooth control, good corrosion and wear resistance, wide temperature range, stability under pressure, etc. are the advantages that a metal-seated ball valve provides with its soft-seated counterparts.

The main differences between soft-seated and metal-seated ball valves are tabulated below:

Soft Seated Ball ValveMetal Seated Ball Valve
Elastic non-metallic material like PTFE, Delrin, Nylon, PEEK, etcMetal Alloys like Copper alloy, Nickel alloy, Chrome Stainless Steel, etc are used as seat material
Used for low or medium temperature and pressure serviceWidely used for high-pressure and temperature services
Low costHigh Cost
High level of SealingComparatively poor sealing
Used for clean services like air, water, etcUsed for severe service conditions like hot water, oil, gas, acid, and other chemicals.
Lower torque requirement for operation.Higher torque requirement
Table: Soft Seated Ball Valve vs Metal Seated Ball Valve

Soft Seat Ball Valve Design

Thermoplastic or Elastomeric seats are inserted in a metallic holder (seat ring) to provide soft seating action in a ball valve. The main features of a soft-seated ball valve are

  • Provide a good sealing ability.
  • Lower in cost than metal seated valves.
  • Limited temperature rating.
  • Should not be used in dirty services, particularly on floating ball valves.
  • Soft seat materials used are – PTFE, Nylon, Devlon, PEEK, etc.
  • It is generally accepted a leakage of ISO 5208 Rate A
Soft Seat Design of Ball Valves
Fig. 2 Soft Seat Design of Ball Valves

Metal Seat Ball Valve Design

The main features of metal-seated ball valves are

  • Direct metal-to-metal contact between seat ring & ball.
  • Ball Valves are used for abrasive service and for services where soft seated valves can not be used due to temperature limitations.
  • The ball & seat contact surfaces are hard-faced to improve resistance to wear & prevent scratching caused by the solid particles contained in the process media.
  • Metal sealing may be obtained by tungsten carbide coating (up to 200 deg. C), chromium carbide coating (above 200 deg. C), electroless nickel plating (ENP), or stellite hard facing.
  • Acceptable leakage of ISO 5208 Rate D.
  • Metal seats do not bed in as easily as soft seals under pressure. hence, ball and sealing rings to be precisely machined.
  • Metal-seated ball valves are posed to pitting, fretting, stress corrosion cracking, and intercrystalline corrosion damages.

3. Ball Valves Types: Reduced bore, Full bore, V-shaped, and Vented ball valves

Based on the inner diameter of the ball valve two types of ball valves are used in industries; Reduced Bore Ball Valve and Full Bore Ball valve.

Reduced Bore (Reduced Port) Ball Valve Design

Reduced port ball valves are quite common in the piping industry. However, reduced bore ball valves introduce frictional losses. The main design features of such ball valves are

  • The bore diameter is 1 size less than the pipe diameter for valve sizes up to 12” NB & 2 sizes less for 14” NB to 24” NB (and 3 sizes less for sizes above 24” NB).
  • These ball valves are comparatively smaller in size with less weight.
Reduced Bore Ball Valve
Fig. 3: Reduced Bore Ball Valve
  • Have lower operating torque, resulting in a lower cost actuated valve package.
  • Slightly higher pressure drop than full bore valve.
  • Prevents pigging
  • These valves are normally of a one-piece – end entry design for smaller sizes (up to 4”-150#) & two / three-piece – side entry design for bigger sizes.
  • These valves are also called regular port valves.

Full Bore (Full Port) Ball Valve Design

Full bore or Full port valves do not cause extra frictional losses, and the system is mechanically easier to clean as it allows pigging.

  • The bore inside diameter is the same as the pipe inside diameter.
  • Very little pressure drop.
  • Ball and housing are bigger.
  • Of higher weight than reduced bore valve, hence more costly.
  • Selected for specific process reasons, typically; minimum pressure drop, minimal erosion, pigging requirement, and gravity flow (to avoid liquid pocket)

V-shaped Ball Valves:

In V-shaped ball valves, The hole in the ball or the valve seat has a “V” shaped profile. This design offers more precise control of the flow rate.

Vented Ball Valves: In a vented ball valve design, a small hole is drilled into the upstream side to eliminate unwanted pressure within the valve.

4. Types of Ball Valves: One-piece, Two-piece, and Three-piece ball valves

Depending on the body construction of valves, there are three types of ball valve designs; One-piece, Two-piece, and three-piece ball valves

Single Piece Body Design Ball Valves

In the single-piece design ball valve, the body will be cast/forged as one piece. The insertion of the ball will be through the end of the body and is held in position by the body insert. This design offers the unique advantage of eliminating the possibility of external leakage to the atmosphere through bolted body joints. This design restricts the ball valve to be of reduced port floating design only (for sizes up to 4” NB).

Single Piece Ball Valve Design
Fig. 4: Single Piece Ball Valve Design

Two-piece  / Three Piece Ball Valve Design

The two-piece design complements the single-piece design in sizes of  6” & above for reduced bore and for FB design valves. In a two-piece design, the body is constructed in two pieces and the ball is held in position by the body stud. There can be a full bore or reduced bore design possible in this construction.

In the case of a three-piece design, the body has two end pieces and one centerpiece. Three-piece design ball valves are most easily online maintainable. By removing the body bolts and keeping only one, the body can be swung away using the last bolt as the fulcrum, to carry out any installation or maintenance operation on the valve. This feature reduces maintenance downtime to a bare minimum.

Multi-piece Ball valve Design
Fig. 5: Multi-piece Design

For larger 2-piece or 3-piece ball valves, the dimensions between the body and flange should be checked so that sufficient clearance is available for bolting. During the vendor drawing review stage, the same should be checked and ensured.

Ball Valve Design
Fig. 6: Ball Valve Design

5. Ball Valve Types: Side entry, Top entry, or welded body ball valves

From the perspective of Ball Valve Body Styles, they are divided into three types of ball valve designs. They are

  • Side entry or end entry ball valves
  • Top entry ball valves and
  • Welded body ball valves

Side entry or end entry ball valve design

In the case of a side entry ball valve, the ball is assembled from the side part. They normally have two pieces or three pieces of the body. Each part of the body is assembled by a bolt/stud similar to joining a two-piece of flanges. Side entry ball valves are usually made by forging the metal. Each piece of the body is forged separately and then assembled together to get the complete design. This construction is robust in design and minimizes the defects caused by casting valves. Side entry ball valves are also easy to assemble and the trim component is also easy to align. Another advantage of the side entry ball valve type is that they are easily available from almost all vendors rather than a casting product that still needs some additional testing.

Top Entry Ball Valve Design

The main design features of top-entry ball valve types are

  • Maintenance and repair of such ball valves are possible in-situ, by removing the top flange. This minimizes maintenance downtime.
  • Limited space is required around the valve for maintenance.
  • Available in welded as well as flanged end connections, but welded ends are preferred to reduce potential leak paths and minimize the ball valve weight.
  • Heaviest and most expensive construction.
Top Entry Ball valve Design
Fig. 7: Top Entry Ball Valve Design

Welded Body Ball Valve Design

The main design features of this type of ball valve design are

  • Welded body ball valve construction eliminates body flanges, reduces potential leak paths, and increases resistance to pipeline stresses.
  • The minimum number of leak paths is hence beneficial in fugitive emission and vacuum applications.
  • Compact and lightweight design
  • The body draining & venting feature allows the ball valve maintenance technician to test each seat ring sealing ability with the ball in either the fully open or fully closed positions.
  • Sealant injection fittings access directly to each seat ring. This enables the technician to top up the quantity of lubricant inside the valve sealant injection system on a periodic basis.
  • Valve cleaner can also be injected into these fittings to flush out the old grease in the ball valve and to clean critical seal faces on the ball.
  • Heavier sealants are also injected through the sealant injection fittings during an emergency when a critical seal is required.
  • Applications – Oil & gas pipelines, compressor stations, measuring skids, etc.
Welded Ball valve Design
Fig. 8: Welded Ball valve Design

6. Ball Valve Types depending on the type of ball design: Floating Ball Valve vs Trunnion Mounted Ball Valves

Depending on the supporting and positioning of the ball, two types of ball valves are used; Floating Ball Valves and Trunnion Mounted Ball Valves

Floating or Seat Supported Ball Valve Design

In a floating ball valve, the ball is not fixed in place and is free to move slightly within the valve body. Sealing is achieved through the pressure of the fluid against the ball.

The major design features of a floating ball valve are

  • Ball valve design in which the ball is not rigidly held on its rotational axis & is free to float between the seat rings.
  • In the closed position, the ball is pushed against the seat by the pressure of the fluid from upstream and hence can pressure seal the downstream of the valve.
  • Ball seats on the downstream seat only.
  • Seat loading increases at a higher pressure and for larger sizes and becomes excessive, for the soft seated valve.  Also, the higher the size the heavier the ball, and the less likely it is to be moved by pressure. Hence the need for a trunnion-mounted ball valve design comes into the picture.
  • Floating design ball valves have lower manufacturing costs.
  •  Valves of small sizes and lower pressure ratings are seats supported (10” for 150#, 6” for 300# & 2” for 600# & above).
  •   The seat-supported design generally needs higher operating torque.
  •   Metal seated floating ball valves also incorporate spring-loaded seats.
Floating Design of Ball Valve
Fig. 9: Floating Design of Ball Valve

Trunnion Mounted Ball Valve

Trunnion ball valves have a fixed ball with a shaft extending through it. This design provides more support to the ball, making it suitable for high-pressure and large-diameter applications. Trunnion ball valves are known for their increased durability and reliability in demanding conditions.

The major design characteristics of a trunnion-mounted ball valve are

  • The ball is fixed in position by the stem & the trunnion which are supported by bearings in the body.
  • The seat is spring-loaded onto the ball, giving reliable sealing at low pressures.
  • The key feature of this ball valve is that the ball does not shift as it does in a floating valve to press the ball into the downstream seat.  Instead, the line pressure forces the upstream seat onto the ball to cause it to seal.
  • As the area on which the pressure acts is much lower, the amount of force exerted on the ball is much less, leading to lower friction values and smaller actuators or gearboxes.
  • Seat designs are either single or double-piston effects.
  • Valves of larger sizes and higher pressure ratings are trunnions mounted.
  • All standard trunnion-mounted ball valves shall be provided with self-relieving seats allowing automatic body cavity relief exceeding 1.33 times the valve pressure rating at 38°C (overpressure due to thermal expansion of trapped fluid).
Trunnion Mounted Ball Valve
Fig. 10: Trunnion Mounted Ball Valve

7. Types of Ball valves: Single vs. Double piston effect design

Based on the pressure relieving capability of the ball valve seats, two types of ball valves are designed; Single Piston Effect Design and Double Piston Effect Ball Valve Design

Single Piston Effect Seat Design

The important design features of single piston effect seat design are

  • Seats of the ball valves are pressed on the ball by means of spring load.
  • As the body cavity pressure increases than the spring load, the seats are pushed back and the pressure is released in the line. This is called a single-piston effect (the pressure in the body cavity is the only acting parameter)
  • Cavity relief to the downstream side, if both the ball valve seats are of single-piston effect design.
  • Each seat is self-relieving the body cavity overpressure to the line.
Single Piston effect Seat Design
Fig. 11: Single Piston Effect Seat Design

Double Piston Effect Seat Design

The design characteristics of a double piston effect seat design ball valves are

  • In this seat design, the medium pressure, as well as body cavity pressure, creates a resultant thrust that pushes the seat rings against the ball. This is called a double piston effect (the pressure in the pipe & that in the body cavity, both are acting parameters)
  • Ball Valves with this design require a cavity pressure relief device to reduce the body cavity pressure.
  • DPE is synonymous with “bi-directional”, and SPE is synonymous with “uni-directional” as defined by API 6D/ISO 14313.
Double Piston Effect Seat Design
Fig. 12: Double Piston Effect Seat Design

The working of Single Pistion Effect and Double Piston Effect Design is clearly shown in the following video:

Single Piston & Double Piston Concepts

Body Cavity Relief (Pressure Equalisation)

  • Ball valves are double-seated valves that incorporate a cavity between the seats.
  • The body cavity will get pressurized only when the seats are damaged.
  • Cavity relief provision is required only for trunnion-mounted ball valves. Not required for floating ball valves as the seats are fixed & the ball is floating.
  • Where possible, cavity relief shall be to the upstream side of the valve.
Body cavity Relief
Fig. 12: Body Cavity Relief

DPE – External pressure relief

  • When the body cavity pressure increases above the net spring load of the pressure relief valve, the cavity pressure is vented through the Pressure Relief Valve.
  • The Relief Valve outlet line can be vented to the atmosphere / connected to the vent system or back to the upstream piping.
DPE – External pressure relief
Fig. 13: DPE – External pressure relief

Combination Seats

  • In some cases, a single-piston effect seat is used for the upstream side and a double-piston effect seat is used for the downstream side.
  • This enables the cavity overpressure to release to the valve upstream side and also doesn’t require an external relief valve.
  • These ball valves are unidirectional and the flow direction is clearly marked on the valve body.

Ball valve Seat Design for Export Line

  • This seat configuration gives a single barrier against normal flow conditions and a double barrier against reverse flow coming from the downstream pipeline.
  • For the ESD/PSD valve, a reverse configuration is required than that shown here. ESD valves require SPE for the upstream seat and DPE for the downstream seat.
Seat Design for Export Line
Fig. 14: Seat Design for Export Line

Pressure Temperature Ratings of Ball Valves

The pressure-temperature ratings of ball valves are decided based on the valve body and sealing materials used for soft-seated ball valves. Sealing materials may be PTFE, 15 to 25% glass-filled PTFE, FPM, NRG, Celastic, POM, Lyton, and Steel. It is very difficult to pre-determine exact pressure-temperature ratings for all kinds of media under all imaginable loading conditions.

The pressure-temperature rating for metal-seated ball valves is decided based on body ratings.

Double Block & Bleed (DBB) feature

When the ball valve is in a fully closed or fully open position, each seat seals off the process medium independently at the same time between the up/downstream and body cavity; it allows bleeding of the cavity pressure through a drain or vent valve. This DBB feature permits in-line periodic inspection of the valves and the checking of sealing integrity when the valve is installed in the line. This feature is available with self relieving seat (SPE) configuration.

DBB Vs DIB

  • If a ball valve has both seats as unidirectional (SPE) seats, it is called a Double Block & Bleed (DBB).
  • If a ball valve has one or both bidirectional (DPE) seats, it is called a Double Isolation & Bleed (DIB).
  • In the DBB valve, the downstream seat pushes away from the valve once the body cavity pressure is higher than the downstream pressure, allowing fluid to flow downstream past the closed valve. In the DIB valve the downstream seat seals and prevents the upstream pressure from reaching the downstream piping.
Double Block & Bleed (DBB) feature
Fig. 15: Double Block & Bleed (DBB) feature

A clear animation of the DBB vs DIB philosophy is presented in the following animation:

DBB vs DIB concept Explanation

Blow-Out Proof Stem Design Feature of Ball Valve

  • When the ball valve is in the open/closed position, the pressure is always acting upon the bottom of the stem, trying to push the stem up.
  • The stem is sealed by o-rings and graphite packing rings.
  • The stem is held in position by the stem housing, which is bolted to the body.
  • The graphite packing rings are compressed and held in position by the gland flange, which is bolted to the stem housing.
  • Therefore, when the gland flange is removed to replace the graphite packing rings, the stem is still held securely, by the stem housing.
  • That means the blow-out-proof stem feature ensures that the top graphite packing rings can be replaced while the valve is under pressure, without the stem being pushed out (blown out).
Blow-Out Proof Stem Design
Fig. 16: Blow-Out Proof Stem Design

Anti-Static Design Feature of Ball Valves

  • The build-up of static electricity can occur as a result of the constant rubbing of the ball against the PTFE seats. This can be a potential fire hazard, especially while handling flammable fluids.
  • In the anti-static feature, spring-loaded balls are provided between the ball & stem and stem & body which provides electrical continuity.
Anti Static Stem Design
Fig. 17: Anti-Static Stem Design

Fire Safe Design of Ball Valves

1) Internal Leakage Prevention (from the pipeline to the body cavity)

  • When non-metal resilient seats are destroyed in a fire, the upstream medium pressure pushes the ball into the downstream metal seat lip to cut off the line fluid and prevent internal leakage due to secondary metal-to-metal seals.
  • Another fire-safe packing is provided at the seat ring for internal leakage prevention to the body cavity.
  • Graphite is normally used as a fire-safe packing material because the melting point of graphite is 1000 degrees C.
Fire Safe Design
Fig. 18: Fire Safe Design

2) External leakage prevention (from body/stem joints to atmosphere)

  • All the possible external leakage points between the stem & gland flange, gland flange & body, and body & adapter are sealed with a primary O-ring and then a secondary graphite gasket. When the fire burns out the primary O-ring seal, the secondary graphite gasket seal can prevent the process medium from external leakage.
  • Fire-safe seals are generally not designed for fugitive emission performance (fugitive emission – emissions of gases or vapors from pressurized equipment due to leaks).
  • The fire testing of valves is carried out as per API 6FA, API 607, ISO 10497, or BS 6755 Part II.
External Leakage Prevention
Fig. 19: External Leakage Prevention

Fire Safe vs. Fire Tested Design

  • Fire-safe design is a design that by the nature of its features and materials is capable of passing a fire test.
  • It is capable of passing a fire test with specified limits on leakage to the atmosphere and downstream after being closed subsequent to fire exposure.
  • A fire-tested design is a design subjected successfully to fire testing as per the applicable testing standard.
  • That means the fire-safe valves are not necessarily fire-tested by the manufacturer.

Ball Valve  Fire Testing Criteria

  • One test valve may be used to qualify valves larger than the test valve, not exceeding twice the size of the test valve.
  • A 16” size valve will qualify all larger sizes.
  • One test valve may be used to qualify valves with higher pressure ratings but no greater than twice the pressure rating of the test valve.
  • The above criteria are acceptable for valves of the same basic design as the test valve & the same non-metallic materials.

Ball valve Sealant Injection System

  • Ball Valves are to be equipped with sealant & lubricant injection connections located at the stem and seat area if specified by the purchaser.
  • The valve design & material selection should negate the need for such a connection.
  • If specified, this injection connection is integrated with a check valve to provide backup sealing, Also a check valve is equipped at the front of seat sealant injection to avoid blowing out in case of the wrong operation.
  • When the soft sealing materials (seat inserts and o-rings) are damaged and leakage happens by fire or other accident, the sealant can be injected through the injection fittings.
Sealant Injection System
Fig. 20: Sealant Injection System
  • The sealant injection system through the seat up to the ball contact circle may provide temporary sealing until it is possible to restore the primary seal.
  • No seat sealant injection shall be provided for ESD valves.

Extended Bonnet Ball Valve

The integrity of stem seals at very low temperatures (-30 degrees C & below) is the major hurdle that must be overcome. Specially designed extended bonnets installed to valves offer a safe & efficient method to accomplish stem seal integrity.

The bonnet extension provides a gas column that allows the gas to vaporize from contact with the warm ambient temperature outside the service line. This vapor column insulates the stem seal and maintains the seal integrity. Bonnet extension also helps with thermal insulation installation.

Extended Bonnet
Fig. 21: Extended Bonnet

Weld Overlay

Sealing areas & other wetted parts of the ball valve can be cladded in case of corrosive service. More frequently used materials for the overlay process are stainless steel, DSS & high nickel alloys. This technology is cost-effective for ball valves in highly corrosive or erosive services. Considerable cost saving without sacrifice to service life or performance. It can be done cost-effectively for sizes 8” and larger. Welding is performed in accordance with ASME BPV section 9.

Weld Overlay
Fig. 22: Weld Overlay

Ball Valve Seat Insert Materials

Thermoplastic seat/seal inserts

Thermoplastic seat/seal inserts
Fig. 23: Thermoplastic seat/seal inserts

Devlon V: Temp. Range -100 deg. C to 150 deg. C

Elastomeric seat/seal inserts

Elastomeric seat/seal inserts
Fig. 24: Elastomeric seat/seal inserts
  • Zero leakage is easier obtained by softer seals (elastomeric), while the resistance to scratches and other factors (temperature, pressure, erosion) is obtained by harder seals (thermoplastic).
  • PTFE is generally not recommended for high pressure (cl. 900 & higher) while it is suitable for a wide range of temperatures and resistant to many fluids.
  • Nylon 12G is more suitable than PTFE for higher pressure but has a limited range in temperature.
  • Nylon 6 should not be used as it absorbs humidity.
  • Devlon V is similar to Nylon 12G but with a wider range of temperature applications (lower & higher)
  • PEEK is recommended for high temperatures (up to 260 deg.C) but it is very hard compared to other nonmetallic materials.
  • Kel-F is especially recommended for cryogenic service.

O-Rings (Elastomeric)

O-rings are used for below applications:

  • Stem seals
  • Seals between seat and body/closure
  • Seals between body and bonnet/closure

Materials are generally as follows:

  • Viton (fluor elastomer)
  • NBR (nitrile butadiene rubber)
  • HNBR

O-rings are not allowed in the seat ring-body joint as well as for the body-bonnet joint. The ball valve seat ring shall have a primary lip seal with a fire-safe graphite ring.

On the stem side, if the seal material specified in the requisition as thermoplastic, it shall be of lip seal type with Inconel 718 spring. If the seal material is specified as elastomeric, it shall be of AED type.

O-rings
Fig. 25: O-rings

Lip Seal

  • For applications where elastomeric O-rings are not reliable, lip seals are used (for body & stem sealing).
  • Lip seals are self-energized seal systems, made of a Teflon cover and a spring (Inconel 718 material).
Lip Seals
Fig. 26: Lip Seals
  • The spring provides the initial load (due to the low elasticity of Teflon), while the fluid pressure provides the load to force the lips on the sealing surfaces.
  • Lip seal housing on CS valves shall be SS316 weld overlayed (3mm thick)

Ball Valve End Connections

The type of ball valve ends are as follows:

  • Flanged ends with raised face or ring joint face
  • Threaded ends
  • Socket weld ends
  • Butt-weld ends – Soft, as well as metal seated butt-welding end valves, shall be provided with butt-weld pup pieces.
  • This avoids damage to the ball valve seat as well as soft seal materials due to welding heat.
  • The pup piece length shall be
    • 200mm for sizes up to 2” NB,
    • 400mm for up to 12” NB size &
    • 800mm above 12” NB sizes

Ball Valve Operator

Ball Valves can be operated by a lever, wrench, or hand wheel or they can be pneumatic, hydraulic, or motor-operated. A ball valve is rotated in a clockwise direction to close & anti-clockwise direction to open. The maximum lever length shall not exceed 450 mm & maximum handwheel diameter shall not exceed the valve face-to-face dimension of 800mm whichever is smaller. A gear operator is required to be provided for valves as per the below criteria:

  • 6” & larger for class 150 ball valves
  • 4” & larger for class 300 & 600 and
  • 3” & larger for class 900 onwards
Valve Operator
Fig. 27: Valve Operator

Ball Valves as ESD Valve

Ball valves as ESD valve application shall be of trunnion mounted type with metal seat design. The minimum size shall be 2” NB. Upstream seats of such ball valves shall be with a single-piston effect and downstream seats with a double-piston effect.

The SPE & DPE shall be marked permanently on the respective seat side and the flow arrow shall be embedded on the ball valve body. However, the valve shall be suitable for bi-directional isolation. The seat ring shall have 2 primary leap seals with a fire-safe graphite ring. The stem shall have a minimum of 2 primary lip seals or U or V-shaped packing with fire-safe secondary seals.

Grease injection fitting shall be provided between primary & secondary seals on the stem side with 2 in-built check valves. No seat sealant injection shall be provided for ESD valves.

Ball Valve Lifting & Supporting Provision

Ball Valves of sizes 8” NB and above or 250 Kg & heavier shall be equipped with lifting lugs. Tapped holes & eye bolts are not acceptable. Ball valves weighing more than 750 kg shall have support lugs and these should be designed to take care of the vertical & lateral loads of valves. The support height shall be as minimum as possible.

Other Requirements of Ball Valves

Drain and vent connections of Ball Valves

Drain and Vent connections shall be drilled & threaded for ball valves up to 900# pressure class & for sizes less than 6” –FB & 8”-RB. The connections shall be fitted with a threaded plug. The plug shall be suitably locked by a locking ring to prevent loosening.

The drain & vent connections for ball valves above 900# pressure class & 6” –FB / 8” -RB  & above sizes shall be fully welded flanged type, fitted with a blind flange. If drain/vent/sealant injection is asked, ensure the orientation of the connections is accessible at the site. During the ball valve vendor drawing review, the same should be checked.

Ball Valve Specification

While purchasing a ball valve, the following information should be provided to the vendor/manufacturer:

  • Ball Valve Size and Pressure Class Rating
  • Type of the Ball: Floating or Trunnion mounted design
  • The pattern of the ball valve: standard or short
  • Bore type: full or reduced bore
  • Ball Valve End Connection type.
  • The requirement of drain connection.
  • The requirement of the Sealant Injection system.
  • The need for a Locking device
  • The requirement of Valve support – if any
  • Anti-Static device
  • Operator Details: Lever/Gear/ Actuator (Electric, Pneumatic, or Hydraulic Operated)
  • The material Valve Body, Seat Rings, Trunnion, Trim, Seals, Gaskets, Bolts, Nuts, and Packing material
  • Seating Type: Soft or Metal Seated
  • Valve orientation
  • Specific Certification requirements
  • The requirement for a Fire-safe test
  • Applicable Painting details
  • The requirement of an Integral bypass connection
  • The requirement of Lugs or Lifting arrangements.

Advantages of Ball Valves

The important Advantages of a Ball valve are listed below

  • Quarter turn straight thru valve / fast opening & closing
  • Tight Shut off as well as very easy to use
  • Application as isolation valve (on and off condition)
  • Suitable for Emergency shutdown conditions
  • Multi-design flexibility
  • Compact, economical designs
  • Suitable for high-pressure service conditions.
  • Long service life.
  • Suitable for a range of industrial applications.
  • Low maintenance

Because of all these benefits, ball valves find wide application in the following industries.

  • Oil & Gas, Chemical, Petrochemical, Refinery
  • Food & Beverage Equipment
  • Vehicle Wash Systems
  • Automotive
  • Home Appliances
  • Power Processing
  • Manufacturing Facilities
  • Pharmaceutical
  • Irrigation & Water Treatment Equipment
  • Chemical Admixtures & Treatment

Disadvantages of Ball Valves

However, there are a few disadvantages of ball valves like

  • Not suitable for throttling
  • Fluid trapped in the body cavity
  • Limited working temperature range

Ball Valve vs. Gate Valve

The major differences between a Ball Valve and a Gate valve are tabulated below:

Ball ValveGate Valve
Ball Valve uses a ball for opening or closingGate valve uses a gate or wedge for opening or closing
The ball Valve is a quarter-turn rotary motion valveA gate valve uses a gate or wedge for opening or closing
The sealing capacity of Ball Valves is comparatively higherComparatively less sealing.
Durability moreLess durability
Quick operation, prone to surgeOperation is slow hence, less probability of surge creation.
More number of valve configurations Less number of valve configurations
More expensiveComparatively low cost
Less CorrosionHigher Corrosion
Low-Pressure DropHigh-Pressure Drop
Table 1: Ball Valve vs. Gate Valve Table

In the realm of fluid control, ball valves stand as a testament to the ingenuity of engineering. Their versatile design, reliable operation, and ability to withstand challenging conditions make them an indispensable component across industries. Whether in oil and gas pipelines, chemical plants, or everyday household systems, the unassuming ball valve plays a crucial role in ensuring the smooth and efficient flow of fluids that power our modern world.

Frequently Asked Questions

What is a ball valve, and how does it work?

A ball valve is a type of valve used to control the flow of fluids. It operates by rotating a spherical ball inside the valve body. When the hole in the ball aligns with the flow direction, the valve is open, allowing fluid to pass through. Rotating the ball to block the hole closes the valve, stopping the flow.

What are the main types of ball valves?

There are two primary types of ball valves:

  • Floating Ball Valves: The ball in these valves is not fixed in place and relies on fluid pressure to create a seal.
  • Trunnion Ball Valves: These valves have a fixed ball with a shaft extending through it, providing additional support and reliability, especially in high-pressure applications.

Where are ball valves commonly used?

Ball valves are widely used across various industries, including:

  • Oil and Gas
  • Water Treatment
  • Chemical Processing
  • HVAC Systems
  • Manufacturing
  • Agriculture
  • Residential Plumbing

What are the advantages of using ball valves?

Some key advantages of ball valves include:

  • Quick and reliable operation
  • Minimal pressure drop
  • Versatility in handling different fluids, temperatures, and pressures
  • Low maintenance requirements
  • Tight sealing to prevent leaks

Can ball valves be used for both on/off and throttling applications?

Yes, ball valves are suitable for both on/off and throttling (partial flow control) applications. However, for precise control in throttling situations, it’s important to choose the right type of ball valve and size it appropriately.

Are ball valves suitable for high-pressure applications?

Trunnion ball valves, with their fixed ball and additional support, are well-suited for high-pressure applications. Floating ball valves are generally used in lower-pressure situations.

Are ball valves suitable for controlling slurries and solid-laden fluids?

While ball valves can handle some solid-laden fluids, they are not the best choice for controlling highly abrasive or viscous slurries. In such cases, specialized valves like knife gate valves or pinch valves may be more appropriate.

Can ball valves be automated for remote control and monitoring?

Yes, ball valves can be equipped with actuators (electric, pneumatic, or hydraulic) for remote control and automation. This is especially useful in industrial processes where precise control and monitoring are essential.

How do I select the right ball valve for my application?

To select the right ball valve, consider factors like the type of fluid, operating temperature and pressure, pipe size, the specific application, end connections, material requirements, flow control requirements, actuation types, etc

Few more useful Resources for you..

Guidelines for the selection of normal valve type
Details about control valves
A brief article on Valve Inspection & Testing
An article on ROTARY SELECTOR VALVE (RSV) and MULTIPHASE FLOW METER (MPFM)
Routing Of Flare And Relief Valve Piping: An article-Part 1
A short presentation on Control Valve Sizing
Basics of Piping Design and Layout
Piping Stress Analysis Basics
Piping Materials Basics

Jacketed Piping: Interview questions and answers

Common questions asked in Piping stress interviews related to Jacketed piping are listed below:

1. Why is Jacketed Piping used?

Ans: It is commonly used to convey very viscous process fluids in an inner pipe, heated by steam/hot water/hot oil or other heating media between the jacket and core pipe. Vacuum jacketing is also used as an insulator for cryogenic fluids and can be analyzed using the same calculation method for heated jacketed piping.    

2. If water (density=1000Kg/m3) is flowing through the jacket then what is the value of density you will enter into the Caesar spreadsheet?

Ans: We have to calculate the equivalent density for the same. The following formula can be used  

Actual jacket fluid equivalent density = [(rj2 – Rc2)/ rj2 ] x dj

Where,        

  • rj  = Inner radius of core Rc = Outer radius of pipe                        
  • dj   =  Density of heating medium

3. What are the major stress checks that you will perform while analyzing the Jacketed Piping system?

Ans:

Sustained And Expansion Stress Check: Limits of calculated stresses due to sustained loads (primary stresses) and displacement strain due to expansion (secondary stresses) should be evaluated separately for core and jacket pipe (as per clause 302.3.5 of ASME B31.3).

Checking of the buckling load. (Manual Calculation):   This check will not be performed by Caesar-II as it is not in the code. However, it will provide force calculated at the junction point (P) between the core and the jacket. It should be less than Pcr which is given by the formula                             

  • Pcr = (4π2 *Ec*Ic)/L2,   For Core         and     
  • Pcr = (4π2 *Ej*Ij)/L2 ,   For Jacket                                                    

Where,                             

  • P = Force calculated by a computer program at the junction point
  • Pcr = Critical force                             
  • Ec, Ej = Modulus of Elasticity of core/ jacket material                             
  • Ic = Moment of Inertia of Core                             
  • Ij = Moment of Inertia of Jacket                             
  • L = length of pipe between the junction of the core/ jacket.

If P ≤ Pcr then no buckling failure ·      

Weld strength check between the jacket and core pipe: P calculated at the junction point between core & jacket pipe compared with allowable load at the weld point.                             

  • P allowed = area of weld * 80% of hot allowable stress of the material
  • Area of weld = π D * root of the weld                             
  • D = Diameter of the core pipe                             
  • The root of weld = 0.707 * weld size
  • If P calculated ≤P allowed, then the system is safe ·      

Checking of deflection of jacket: In this case, it is assumed that no spider/spacer is used between the core and jacket. The deflection for the jacket with available length has to be computed and should be ensured that it does not create an obstruction to the flow of hot medium in the jacket. Normally maximum allowed deflection of the jacket is T/2, where T is the thickness of the jacket.

Checking for External Pressure (By material Group):   Sometimes the jacket may be subjected to partial vacuum conditions due to failure of the steam supply and subsequent condensation of steam inside the jacket. In such cases, the jacket should be checked for vacuum conditions. As another example, in a system, the core is at a pressure of 30 PSIG and the jacket is at a pressure of 180 psig, then the core is subjected to an external pressure of 150 PSIG. For this, the core must be investigated for collapse or local buckling from the external pressure load (Refer para 304.1.3 of ASME B31.3 and UG-28 through UG-30 of ASME BPVC Section-VIII Division-I)   ·     

Checking for Axial Stress:   As per ASME B31.3, the calculated displacement stress range (Expansion case stress) is SE = (Sb2 + 4St2)1/2. The code does not take into account the axial forces and consequent axial stress in calculating expansion stresses. This is because for the normal pipe axial forces are normally due to longitudinal stresses which are already taken care of in thickness calculation and sustained stress calculations, but in the case of jacketed piping, axial stresses at the core-jacket junction point are just not due to longitudinal stresses, but mainly due to differential thermal expansion of core and jacket pipes. Thus calculated stress should be corrected by adding axial stresses for local analysis of that particular junction point. Thus,                                         

Actual Stress SEa = SE + Axial Force/ Area Axial force can be obtained from CAESAR output or can be calculated by the equation,

Faxial = (E x ΔL x Area) / L

Or else, CAESAR also calculates the value of axial stresses which it calculates for operating cases. Activate the option “Add F/A in stress” in the configuration file. Axial stress due to thermal differential is added to the calculated expansion stress and then it should be compared with the allowable loads as per ASME B31.3.

4. What allowable value is considered for welding check at core jacket interconnection?

Ans: Two methods are prevalent. You have to consider any one of the following (discuss with the stress lead) a) Consider the 0.6 times electrode tensile strength (As per AISC code) b) Consider SE=1.25Sc+0.25Sh of the electrode as allowable (as per secondary stress generated theory)