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Previous Issue: 25 January 2006 Next Planned Update: 30 November 2012 Page 1 of 35 Primary contact: Sabban, Mahmoud Abdulrahim on 966-3-8760124
Copyright©Saudi Aramco 2007. All rights reserved.
Materials System Specification
32-SAMSS-100 1 December 2007 Combustion Gas Turbines
Gas Turbines & Diesel Engines Standards Committee Members Sabri, Hasan Abdulrahman, Chairman Sabban, Mahmoud Abdulrahim, Vice Chairman Beckenbach, Joseph William Fagihi, Ali Saoud Hussain, Khaleel Ma'Atug Issa, Mohammad Abdallah Jamea, Khalid Hamad Khalifah, Khalifah Sa'Ad Khowaiter, Abdul Rahman Othman Odan, Nabeel Mohammad Saeed, Mustafa Taher Saffar, Adel Abdullah
Saudi Aramco DeskTop Standards Table of Contents 1 Scope............................................................. 2 2 Conflicts and Deviations................................. 2 3 References..................................................... 2 4 General…………………………………………..4 5 Design............................................................ 8 6 Inspection..................................................... 31 7 Testing.......................................................... 31 Appendix I – Definitions...................................... 34
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1 Scope
1.1 This Specification defines the mandatory minimum requirements for design,
manufacture and installation of gas turbine packages for the applications of
mechanical and power generation drives. This entire Specification may be
attached to and made a part of purchase orders.
1.2 The gas turbine package includes a base frame or a plate, accessory and
auxiliary systems for starting, stopping, protecting, controlling and monitoring
the gas turbine.
2 Conflicts and Deviations
2.1 Any conflicts between this Specification and other applicable Materials System
Specifications (SAMSSs), Standard Drawings (SASDs) or industry standards,
codes and forms shall be resolved in writing by the Company or Buyer
Representative through the Manager, Consulting Services Department, Saudi
Aramco, Dhahran.
2.2 Direct all requests to deviate from this Specification in writing to the Company
or Buyer Representative to be forwarded to the Manager, Consulting Services
Department, Saudi Aramco, Dhahran.
3 References
The selection of material and equipment and the design, construction, and repair of
equipment and facilities covered by this Specification shall comply with the references
listed below, unless otherwise noted.
3.1 Saudi Aramco References
Saudi Aramco Materials System Specifications
32-SAMSS-008 Inlet Air Filtration Systems for Combustion Gas
Turbines
34-SAMSS-625 Machinery Protection Systems
34-SAMSS-831 Instrumentations for Packaged Units
Saudi Aramco Standard Drawing
AB-036322 Sht. 001 Anchor Bolt Details – Inch and Metric Sizes
Saudi Aramco Forms and Data Sheets
7305-ENG Equipment Noise Data Sheet
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8002-ENG & Combustion Gas Turbine Data Sheets
8002-M-ENG
Saudi Aramco Inspection Requirements
Form 175-325501 Combustion Gas Turbine Package
thru 325519
Saudi Aramco Product Specification
A-888 Diesel
3.2 Industry Codes and Standards
American Concrete Institute
ACI 318 Building Code Requirements for Structural
Concrete
American Institute of Steel Construction
AISC Code of Standard Practice for Steel Buildings and
Bridges
American National Standards Institute
ANSI MC96.1 Temperature Measurement Thermocouples
American Petroleum Institute
API STD 614 Lubrication, Shaft Sealing and Control Oil
Systems for Special Purpose Applications
API STD 616 Gas Turbines for Refinery Services
American Society of Mechanical Engineers
ASME B1.21.1 Pipe Threads, General Purpose
ASME B16.5 Pipe Flanges and Flanged Fittings
ASME B31.1 Power Piping
ASME PTC 1 General Instructions (Performance Test Code)
ASME PTC 4.4 Performance Testing of Heat Recovery Steam
Generation
ASME PTC 22 Performance Test Code on Gas Turbines
ASME SEC VIII Boiler and Pressure Vessel Code/Pressure Vessels
ASME SEC IX Standard for Welding and Brazing Procedures
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International Electrotechnical Commission
IEC 60502-1 Power Cables with Extruded Insulation and
theirAccessories for Rated Voltages from 1 kV
up to 30 kV - Part 1: Cables for Rated Voltages
of 1 kV and 3 kV
NACE International
NACE MR0175 Materials for use in H2S-containing
2002 Edition Environments in Oil and Gas Production
US Environmental Protection Agency
USEPA Method 1, Section 2.5, Gas Flow Angles and Sampling Procedure
40 CFR 60, Appendix A
National Fire Protection Association
NFPA 12 Carbon Dioxide Extinguishing Systems
NFPA 70 National Electric Code
NFPA 72 National Fire Alarm Code
Process Industry Practices
STF05501 Fixed Ladders and Cages
STF05511 Fixed Industrial Stairs
STF05520 Pipe Railing for Walking and Working Surface
Details
STF05521 Details for Angle Railing for Walking and
Working Surfaces
STF05530 Grating Details
4 General
4.1 Gas turbine units shall be supplied by Vendors qualified by experience. To
qualify, the Vendor must have manufactured at least two turbines of identical or
greater speed, firing temperature and power rating for operation on fuels of
similar specification. These turbines must have been in continuous service for at
least two (2) years and must be performing satisfactorily. Both the gas turbine
and inlet air filter element vendors shall be selected from Saudi Aramco
Regulated Vendor List (RVL).
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Alternatively, the Vendor may satisfy this experience requirement based on an
individual component life in comparable or more severe service conditions.
Experience need not be concentrated in a single turbine unit but may be spread
through separate operating turbine components such as gas generators and
power turbines. To qualify, however, each of the referenced turbines must have
been in continuous service for at least Two (2) years and must be performing
satisfactorily.
For vendors new to Saudi Aramco, documentation substantiating the Vendor's
prior experience and existing resources and capabilities shall be submitted
through the Company or Buyer Representative to be reviewed for compliance by
the Chairman, Gas Turbines & Diesel Engines Standards Committee, Consulting
Services Department prior to order placement. The Vendor shall provide
contact names of other Users and locations of shipped units to enable
verification of satisfactory field operation of referenced turbines. Also, the
vendor shall provide a list of all approved repair shops.
When other fuels such as natural gas liquids, liquefied petroleum gas, crude oil,
residual fuel oils and heavy distillate fuels are used, the Vendor shall provide, as
part of the experience qualifications, documented evidence of prior successful
experience of burning the contract defined fuels in the proposed turbine and the
effect on turbine rating, availability, reliability, parts life and frequency of
inspections and overhauls.
4.2 ISO Rating
4.2.1 The Vendor shall identify location of inlet and exhaust conditions used
in determining the unit's performance. Typically, the inlet conditions
are measured at the compressor inlet flange and the exhaust conditions
are measured at the turbine exhaust flange.
4.2.2 When required, the power is measured at the output shaft for
mechanical drive units. For generator trains, the power is measured in
MWe at the generator output terminals.
4.3 Life Requirements
4.3.1 The life requirements for major components shall be based on a base
load operation, burning natural gas fuel, and a minimum of 90 annual
starts (or more), with an average of 100 hours between starts.
4.3.2 For both the aero-derivate and heavy duty industrial combustion gas
turbine (CGT) units, the Vendor shall submit the following in the
proposal to be used in the Life Cycle Cost (LCC) analysis:
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a) A detailed breakdown of the unit required inspection intervals for
dry natural gas fuel at base load operation condition, and for
other fuels when specified in the data sheets. The information
shall include manhours to perform typical inspections, outage
times, and correction factors for inspection intervals for different
loads and number of starts.
b) A detailed maintenance plan, including parts replacement
schedule for a 20 years period and a certified current cost of
spare parts.
c) The fleet reliability and availability figures.
4.4 Performance, Power, Speed and Emission Requirements
4.4.1 The Vendor shall account for and provide all performance correction
factors (from ISO conditions) including the effects of temperature,
elevation, humidity (maximum humidity at site maximum
temperature), and gearbox, transmission, and other losses, if any.
4.4.2 Packages used for mechanical drive or power generation, which are not
connected to the national electric grid, shall have a guaranteed
available power (hp, kW), at the site rated conditions, of 10% or
greater above the required load.
4.4.3 The following information shall be also included in the Vendor's
proposal and in the operating and maintenance manual (O&M):
a) Performance curves (or correction factors) of the following
parameters versus compressor inlet or ambient temperature;
Power output and heat rate.
Inlet and exhaust airflow rates.
Heat rate versus load.
Exhaust temperature versus load.
Exhaust flow rate versus load.
Maximum and Minimum continuous speed.
b) The following curves shall also be submitted by the Vendor:
For Mechanical drive units, the output shaft power and heat
rate versus output shaft speed for the specified speed range
(e.g., 50% to 105 %) at the site rated conditions.
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Inlet and exhaust pressure drop effects (including inlet filters,
inlet and exhaust silencers and inlet and exhaust ducts) on the
unit output shaft power and heat rate.
Expected performance degradation curve versus time (e.g.,
power output & efficiency (performance loss) versus number
of equivalent operating hours).
Output power and heat rate curves versus ambient humidity.
c) Output Shaft Speeds (for mechanical drive units):
Output shaft speed(s), at design and at rated conditions.
The maximum continuous speed; this shall be at least equal to
105% of the highest speed required by the driven equipment.
The minimum operating speeds.
The shaft(s) critical speeds.
d) Minimum and maximum generator power output.
e) Load factors for power generation units.
f) Load-gear load limits, if applicable.
g) Emissions (i.e., NOx & CO) curves across the proposed unit's full
operating range and emission correction curves of all impacting
parameters.
h) Reference list of similar engines to include contacts of current
users.
4.5 Unless otherwise specified, the turbine Vendor is assigned the responsibility for
the complete train (including driven equipment and related auxiliaries). This
responsibility means trouble-free startup and operation for the specified
operating hours of the entire train of equipment comprising gas turbine, power
transmission, driven equipment and accessory and auxiliary equipment. This
responsibility shall include the following:
- Common control system;
- Power transmission components;
- Equipment layout and baseplate design, if applicable;
- All vendor supplied accessory and auxiliary equipment, including the
supplied fuel and lube oil systems;
- Monitoring and protection systems;
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- GT compressor washing systems;
- GT turbine washing system if ash forming fuels are specified;
- Performance and guarantee of the complete train;
- Lateral and torsional dynamic analyses;
- Noise attenuation.
4.6 The Vendor shall provide parts lists as follows:
- Spare parts and consumables for the first two years of operation.
- Parts and consumables for a combustion inspection.
- Parts and consumables for a hot gas path inspection.
- Parts and consumables for a major inspection.
- Major components with a life expectancy less than 20 years. [i.e., turbine
nozzles (if applicable), blades, combustion liners and transition pieces (if
applicable), rotors (if applicable), compressor blades, inlet guide vanes, inlet
and exhaust ducts, expansion gaskets, inlet and exhaust silencers, lube oil
coolers, motors, pumps, gears, etc.]
4.7 The Vendor shall provide a list of the equipment requiring emergency power.
5 Design
5.1 General
5.1.1 Mechanical drive gas turbine packages shall comply with API STD
616, fourth edition. Manufacturer's standard design is acceptable
provided that it complies with this engineering specification's
requirements, and a list of exceptions to API STD 616 is provided for
review by the Chairman, Gas Turbines & Diesel Engines Standards
Committee, Consulting Services Department.
5.1.2 If applicable, the auxiliary gearbox shall be of the manufacturer's
standard design which has been proven in either an identical or at
minimum in a similarly loaded and operated unit.
5.1.3 The proposed gas turbine unit auxiliary systems shall be suitable for
both the lowest and highest site ambient temperatures.
5.2 Enclosures
5.2.1 For outdoor operation, the gas turbine shall be packaged in an
enclosure. For indoor operation, the gas turbine shall be either in an
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enclosure or free standing. The Vendor shall provide, on the Data
Sheet, the heat rejection rate from the unit to the building.
5.2.2 Maintenance provisions and equipment for lifting the heaviest gas
turbine components shall be provided (e.g., overhead cranes lifting
beams and cranes inside accessory compartments).
5.2.3 Removable sections in the lagging shall be furnished to facilitate
access and removal of compressor upper half casing, combustors and
the turbine section casing.
5.2.4 All lighting within the local control compartments and walk-in type
enclosures shall be furnished and installed. Installation shall be in
accordance with NEC or IEC.
5.2.5 A ventilating purge air system shall be provided for the accessory
compartment, gas turbine compartment and purged exhaust stack,
where applicable. This ventilation air shall be taken from the clean air
plenum of the inlet air filter housing. The system shall have an
installed spare motor driven fan.
5.2.6 All doors shall be equipped with panic bars.
5.3 Compressor
5.3.1 When possible, the Vendor shall provide the option for coated
compressor stage if the coating is not standard. This information shall
be submitted through the Company or Buyer Representative for review
by the Chairman, Gas Turbines & Diesel Engines Standards
Committee, Consulting Services Department.
5.3.2 The unit shall be equipped with a compressor off-line and on-line
washing systems. The manufacturer shall provide instructions for both
off-line and on-line washing and shall list allowable cleaning
detergents/chemical and recommended washing frequencies and
instrumentation to be disconnected during the wash cycle.
A manual drain valve shall be provided at the lowest point of the
compressor casing. The drain line shall be piped and flanged to skid
edge.
5.3.3 The starting device shall be used to crank the compressor rotor for off-
line washing.
5.3.4 The unit control shall include a drying cycle which can be selected by
the operator to start the unit after off-line washing.
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5.4 Combustor
5.4.1 The Manufacturer shall provide allowable variation of the Wobbe
Index for the gaseous fuel(s) specified in the data sheet.
5.4.2 An automatic drain valve shall be provided at the lowest point of the
combustion casing to drain any liquid that may enter the combustion
casing when the unit is shut down. A manual valve shall also be
provided in the drain line, downstream of the automatic valve, at an
easily accessible location. The drain line shall piped and flanged to
skid edge.
5.5 Turbine
5.5.1 The turbine shall be capable of a hot restart at any time after a trip. If
this cannot be achieved, the Vendor shall specify the pre-cooling
interval between start attempts required by the turbine under any
operating conditions, and shall be supplied for review and approval by
the Chairman, Gas Turbines & Diesel Engines Standards Committee,
Consulting Services Department. This pre-cooling interval should be
part of the re-start logic of the control system.
5.5.2 When crude oil is used as fuel, the unit turbine section shall be
equipped with off-line washing system. The manufacturer shall
provide complete washing instructions and recommended washing
frequencies.
5.5.3 If heat exchangers are used to cool the turbine cooling air, then an
installed spare shall be provided (e.g., 2x100%,1x100% with 3x50%
fans). The heat exchanger design shall comply to section 5.9 of this
SAMSS.
5.6 Inlet Air System
5.6.1 The inlet air system, up to and including the inlet plenum, shall be in
accordance with 32-SAMSS-008. The filtration system shall be a self
cleaning type.
5.6.2 A manometer or pressure sensor readout shall be provided at the
turbine inlet flange, with connection to the turbine control.
5.6.3 The inlet silencers shall be corrosion resistant Manufacturer's standard
design. If coating is used, it shall be zinc free.
5.6.4 A bulkhead double lock type gasket-sealed access panel or bolted
manhole shall be provided to access the interior of the plenum
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5.6.5 Two safety glass viewing window, one on each side of the inlet
plenum, shall be provided as per manufacturer's standard design. The
height of the viewing window shall not exceed 1.6m above grade,
platform, or walkway.
5.6.6 The inlet plenum and the inlet duct shall have drain pipes installed in
all low points. The bottom of the inlet plenum shall slope away from
the compressor inlet flange towards the drains. A slope of 3/1000 to
5/1000 is acceptable. The drain pipe diameter shall be 25 mm (1 in)
minimum, and 50 mm (2 in) minimum for units with evaporative
coolers. The drains shall slope downwards continuously and shall be
connected to a common trap fitted with an automatic drain valve.
Failure of the automatic drain valve shall be indicated by an alarm.
The drain system shall be configured such that the maximum liquid
level shall not be less than 250 mm (10 in) below the bottom of the
inlet plenum.
The drain system shall be air tight. In areas where rain can enter the
inlet air system, a water droplet catcher shall be installed.
5.6.7 Drain holes open to atmosphere in the plenum low points are not
acceptable.
5.7 Exhaust System
5.7.1 The discharge of the gas turbine exhaust gases shall be outside of a
three-dimensional fire hazardous zone.
5.7.2 The exhaust stack discharge shall be at least 3 m higher than any
platform or access within a horizontal distance of 7.5 m.
5.7.3 The exhaust stack shall discharge outside any classified electrical area.
5.7.4 The turbine exhaust stack external surface temperature shall not exceed
230°C to a height of ten (10) feet above grade and platforms.
5.7.5 Where personnel protection and/or reduction of heat rejection are
required, external insulation shall be installed on any surface up to ten
(10) feet above grade, walkways, and platforms. The exposed surface
temperature shall not exceed 70°C.
5.7.6 The exhaust duct and expansion joints shall be provided by the
Vendor.
5.7.7 A pressure indicator shall be provided at the turbine exhaust plenum.
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5.7.8 The exhaust plenum and the exhaust silencers shall be Manufacturer's
standard. The exhaust plenum shall be provided with an access
manhole (i.e., between the exhaust diffuser and silencers) at grade level
or access platform if located above grade. The turbine Manufacturer
shall also supply any required extensions to the supporting structure
and safety provisions for personnel protection.
5.7.9 Emission sampling ports shall be according to referenced USEPA
Method 1, Section 2.5, 40 CFR 60. Emissions sampling ports are also
possible after the diffuser in the vertical plane.
5.8 Couplings
5.8.1 All couplings shall be of the dry, flexible diaphragm or disc type. If
the load is higher than the capability of flexible couplings, solid
couplings may be provided.
5.8.2 For mechanical drive units, the Vendor shall offer, as optional, a torque
metering load coupling designed for continuous operation. The
coupling monitor display shall include torque, speed and power. Strain
gauge type couplings are not acceptable.
5.9 Fuel System
5.9.1 The proposed gas turbine unit shall be designed to operate on the
primary and backup fuels.
5.9.2 For gaseous fuels, the proposed unit shall be capable of handling the
fuels specified in the data sheets without requiring any hardware or
software modifications.
5.9.3 The on-skid fuel gas piping shall be SS 316L and of the manufacturer's
proven standard design. In addition, all fuel piping welds shall be
subjected to 100% inspection (radiography, magnetic particle, dye-
penetrate). If sour gas is used as fuel, then fuel gas piping shall be in
compliance with NACE MR0175, 2002 Edition.
5.9.4 Strainer
A fuel gas strainer with a differential pressure gauge shall be provided
loose to be installed upstream of the gas supply connection to the
turbine fuel delivery interface flange. The internals of this strainer
shall be corrosion resistant stainless steel.
5.9.5 For liquid fuel burning unit, the extent and method of liquid fuel
treatment shall be determined for each project individually and shall
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depend on the fuel quality (grade) and the requirements of individual
turbine make and type. Proposals by the Vendor for burning liquid
fuel shall detail the fuel specification treatment required. Proposals
shall be submitted through the Company or Buyer Representative for
review and approval by the Chairman, Gas Turbines & Diesel Engines
Standards Committee, Consulting Services Department.
5.10 Lube Oil and Hydraulic Oil Systems
5.10.1 General
5.10.1.1 The lube oil system shall comply with API STD 614 latest
revision, for mechanical drive, and with ASME B31.1 for
power generation units. The system shall also comply with
the requirements noted in this specification. The list of
deviations, where applicable, to this Specification shall be
submitted for review by the Chairman, Gas Turbines &
Diesel Engines Standards Committee, Consulting Services
Department.
5.10.1.2 If the lube oil system is custom designed (not the
Manufacturer's standard construction), it shall be sized to
handle both the turbine and the driven equipment. Also,
when space limitation exists, as may be the case on an
offshore production facility, a combined lube oil system
shall be specified. The custom design lube oil system shall
comply with Chapter 1 & 2 of API STD 614, Fourth
Edition, and the requirements noted in this specification.
5.10.1.3 Provisions shall be made for bypassing the bearings of the
unit and driven equipment during lube oil system flushing.
5.10.1.4 The hydraulic oil system, if applicable, shall be of the
manufacturer's proven standard design.
5.10.2 Lube Oil Reservoir
5.10.2.1 The location of the lube oil reservoir shall be in accordance
with the Manufacturer's standard construction. If the lube
oil system is to be custom designed, the reservoir shall be
separate from the turbine baseplate.
5.10.2.2 The reservoir retention time shall be in accordance with the
Manufacturer’s standard design, but not less than 5 minutes,
based on normal flow and retention capacity.
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5.10.2.3 The reservoir shall be either stainless steel or internally
coated carbon steel. However, welding to the oil tank is not
permitted if the tank has already been coated.
5.10.2.4 Lube oil return flow may enter the oil tank below the
nominal oil level, provided that no foaming takes place and
it is the Manufacturer's standard method, and is supported
by extensive field experience with satisfactorily continuous
service of at least one year.
Features to minimize the potential of oil foaming shall be
part of such set up. Information pertaining to oil tank
material, coating and oil return flow setup shall be
submitted by the Manufacturer through the Buyer or
Company Representative for information to the Chairman,
Gas Turbines & Diesel Engines Standards Committee,
Consulting Services Department.
5.10.3 Lube Oil Coolers
Lube oil coolers shall be of the manufacturer's proven standard design
for the site condition (e.g., marine, desert, etc.), with the following
exceptions and additions:
5.10.3.1 An installed spare shall be provided (e.g., 2x100%,1x100%
with 3x50% fans).
5.10.3.2 Oil-to-water coolers shall be provided with air venting
feature on water side.
5.10.3.3 Fin fan coolers shall be provided with 316L stainless steel
material tubes and heads. All other coolers’ material of
construction shall be submitted for approval to the
Chairman, Gas Turbines & Diesel Engines Standards
Committee, Consulting Services Department.
5.10.3.4 Brush (wire mesh) type turbulators for cooler internals are
not acceptable.
5.10.3.5 The minimum cooler design airside fouling resistance shall
be 0.000352 m² °K/W (0.002 ft² h °F/Btu).
5.10.3.6 The minimum cooler design inlet air temperature shall be
the summer dry bulb temperature at 1.0% plus 4.4°C (8°F).
5.10.3.7 U-bends in air coolers are not allowed
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5.10.3.7 The vendor shall advise the Buyer of the cooled oil
temperature achievable under specified maximum ambient
temperature conditions. In no case shall the lube or seal oil
temperature downstream of the cooler exceed 60˚C (140˚F).
5.10.3.8 The lube oil cooler fan motors shall be equipped with
siezmic vibration probs.
5.10.4 Lube Oil Filters
5.10.4.1 Dual lube oil filters shall be provided. The filter elements
shall be of the disposable cartridge type.
5.10.4.2 Lube oil filter switchover valves shall be provided, and
shall only switchover between the filters. Valves
removal/reinstallation for maintenance shall not require
cutting/welding.
5.10.4.3 Lube oil filter switchover during operation shall not affect
the unit operation.
5.10.4.4 Differential pressure device across the filter shall be
provided with an alarm.
5.10.5 Lube Oil System Piping
The lube oil system supply piping, downstream of and including the
lube oil filters, shall be 316L Stainless Steel or better. Carbon steel
valves with stainless steel trim are acceptable.
5.11 Piping and Tubing (General)
5.11.1 All threaded process connections shall be tapered per ASME B1.21.1.
5.11.2 All flanged process connections shall conform to ASME B16.5.
5.11.3 Flexible hoses/piping shall be with integral connectors.
5.12 Starting System
5.12.1 The type of starting system shall be as specified in the datasheets.
5.12.2 Starting system associated diesel engines, electric motors, and steam
turbines shall be of the manufacturer's proven standard design. The
starter steam turbine shall be equipped with its own overspeed
protection system.
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5.12.3 The starting system shall be of the manufacturer's proven design, but
capable of a minimum of three consecutive start attempts. The Vendor
shall specify waiting periods required between starts for recovery of
the starting system for various operating conditions.
5.12.4 For mechanical drives, the torque curve of the driven equipment shall
be obtained from its supplier. As a minimum, the torque curve shall be
provided from zero speed to self-sustaining speed of the train.
5.12.5 If black start capability is specified, the starting device shall be a diesel
engine or an electric motor fed from a dedicated diesel generator
supplied by Buyer.
5.13 Controls and Instrumentation
5.13.1 Gas Turbine Control System (TCS) shall be of the manufacturer's
standard design. Third party control systems may be allowed only if
the gas turbine manufacturer does not offer its own control system.
5.13.2 The control system shall be electronic, microprocessor based, and fully
redundant. Wherever feasible, a single control system for both the
CGT and driven equipment is desired.
5.13.3 The turbine control function shall include starting, operating, stopping,
protecting, monitoring and cleaning (on-line and off-line) of the gas
turbine unit.
5.13.4 The control system shall be installed in an air conditioned cabin
located in the vicinity of the unit. The control cabin shall be as per
paragraph 5.18 of this SAMSS.
5.13.5 The starting cycle sequence shall be automatic, unless otherwise
specified. The operator shall be able to pause the start up cycle at
certain safe steps (e.g., system check, purging, idle) and return to a
previous step in the start up cycle (one at a time) without subjecting
the unit to any damage or unsafe operation. The operator shall also be
able to abort the start up at any point during the start up cycle.
5.13.6 The control system shall provide a purge period to displace three to
five times the entire volume of the gas turbine and the inlet and
exhaust systems, before firing the unit.
5.13.7 The control system shall have an independent Uninterrupted Power
Supply (UPS) capable of supplying power sufficient to achieve a safe
and orderly unit shutdown. The UPS shall be of manufacturer's
standard on-line type.
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5.13.8 Radio Frequency Interference (RFI), from sources such as hand-held
radio transceivers operating at 5 watts within the frequency ranges ,
50-174 MHz, 406-470 MHz, and 800-870 MHz, and held at a distance
of 1.0 meter from the control equipment shall not cause any
malfunction, data corruption or damage to the turbine control
equipment.
5.13.9 For generator drive gas turbines, the speed governor system shall be
capable of adjusting through a range of plus/minus 4% of synchronous
speed before synchronization.
5.13.10 For generator drive gas turbines operating in an isolated island mode
and are under load, the governor shall regulate the speed within
plus/minus 4% droop when going from half load to full load.
5.13.11 The proposal shall contain a statement of the permissible maximum
value of the steady state speed regulation for which the speed
governing system may be adjusted.
5.13.12 Power generating units shall be capable of maintaining the load despite
a sudden loss of the parallel or back up power supply (e.g., supplied
from a national electric power grid). The units shall also have the
capability and facility to synchronize back with the grid power supply
while it is carrying the connected load.
Commentary Note:
The intent of 5.13.12 is to assure that the GT will be able to supply the required power if the main grid power supply is disconnected for whatever reason, without any limitations imposed on plant's operation.
5.13.13 For heavy industrial units, vibration measurement and monitoring shall
be provided on all bearings. The following instrumentation shall be
provided:
- One event per revolution sensor (key phasor) on each shaft.
- Journal bearings shall have radial shaft relative displacement
sensors (X-Y probes) mounted at 45° from the vertical centerline.
- Bearing housings shall have a piezo-velocity seismic transducer
displaying vertical velocity in RMS.
- The thrust bearings shall have dual probes with voting logic
monitoring the axial position.
- For probes requiring cooling, the Vendor shall specify the cooling
air quantity and quality.
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Installation and calibration shall be in accordance with 34-SAMSS-625.
5.13.14 For aero-derivative engines, vibration measurement and monitoring
shall be per the Vendor's standard. A minimum of two transducers are
required, one on the compressor casing and one on the turbine casing.
Both transducers shall be used for alarm and emergency shutdown.
Installation shall be in accordance with 34-SAMSS-625.
The driven equipment shall be equipped with a minimum of a
keyphasor, and proximity probes measuring radial and axial directions
on each bearing housing, as applicable.
5.13.15 For heavy industrial units, bearing lube oil drain thermocouples or
RTD shall be provided for every bearing. One common thermocouple
in a combined drain is not acceptable, except for bearings with
common cavities. Hydrodynamic thrust and radial bearings shall each
have either an RTD or a thermocouple installed in a pad that is
expected to read the highest temperature. Lube oil drain
thermocouples shall be utilized for alarm and emergency shutdown.
Installation shall be in accordance with 34-SAMSS-625.
5.13.16 The speed sensor shall be either of magnetic or inductive pick-up type.
5.13.17 For turbines equipped with rolling element bearings, on-line metal chip
detection instrumentation shall be provided in each bearing lube oil
drain line. Annunciation of detected chips or debris shall be provided
in the plant control room.
5.13.18 The instrumentation system shall comply with the electrical area
classification requirements designated in the Purchase Order or on the
approved electrical area classification drawing.
5.13.19 The arrangement, grouping and number of panels for instrumentation
shall be in accordance with the Manufacturer's standard.
5.13.20 The control system shall have a redundant connection, MODBUS or
Ethernet, with the Human Machine Interfacte (HMI) and with the plant
Distributed Control System (DCS).
5.13.21 Alarm and shutdown systems shall be of fail-safe design.
5.13.22 Control system cabinets shall be rigid, self-supporting and made of
metal.
5.13.23 Cabinets requiring heat dissipation shall be convection-ventilated and
provided with readily accessible, removable filter screens inserted
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behind slotted louver inlets. Louvers and filters installed within cabinet
doors are acceptable. If fans are used to assist in heat removal and are
required to dissipate heat when the HVAC is running, redundant fans
shall be provided.
5.13.24 Interiors of floor-mounted digital cabinets containing power supplies
shall be monitored by an addressable high-sensitivity air sampling or
point-type smoke detection system. The detection systems shall have
at least two adjustable set points. All sensing devices shall be
addressable to the local fire panel. Each cabinet requires an
individually identifiable smoke detection end device so that the fire
panel will identify which specific cabinet is generating the alarm.
Air sampling tubes or pipes for high sensitivity smoke detection
systems shall be steel or otherwise have a flame spread rating not over
25 without evidence of continued progressive combustion and a smoke
developed rating no higher than 50 or otherwise be UL listed
specifically for air sampling smoke detector service. Use of unrated
PVC pipe or tubing is not allowed.
5.13.25 The instrument piping and tubing materials and installation shall
ensure the reliable and accurate operation in the working environment
of the instrument(s) involved, and allow sufficient access for
maintenance, calibration and testing.
5.13.26 Instrument tubing shall be adequately supported to eliminate any
vibration transmission to the instruments or excessive load to the
piping connection.
5.13.27 Each instruments tubing shall be equipped with block valve (root
valve) for isolation and maintenance of the associated instrument only.
5.13.28 instrument enclosures shall be stainless steel or copper free aluminum
and shall be rated as NEMA 4X or IEC Type IP 65.
5.13.29 all shutdown initiating devices shall be redundant.
5.13.30 Emergency shutdown buttons shall be provided on both sides outside
of the gas turbine enclosure. Buttons shall be of the pull type not push
type.
5.14 Wiring
5.14.1 General power wiring, for circuits up to 600V to ground and a
maximum current rating of 15A, shall be stranded copper; flame
retardant PVC, XLPE or XLPO insulated; size 14 AWG minimum;
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have an insulation minimum temperature rating of 90°C and shall
comply with NFPA 70 or IEC 60502-1.
5.14.2 Instrumentation signal wiring shall be stranded copper; flame retardant
PVC, XLPE or XLPO insulated. The minimum wire size shall be:
a) 16 AWG single twisted pair/triad from instruments to the nearest
skid mounted junction box. Cables carrying analog signals shall
also be shielded. Smaller wire size may be accepted if
substantiated by field experience and a written approval is
obtained from the Chairman, Gas Turbines & Diesel Engines
Standards Committee, Consulting Services Department.
b) 18 AWG for multi-twisted pair/triad cables from junction boxes
to other junction boxes, marshalling cabinets, or control system.
c) 22 AWG for multi-conductor cable inter-cabinet wiring.
5.14.3 Pair/triads of multi-twisted pair/triad control cables shall be numbered.
5.14.4 Except for thermocouple wiring,
a) Power and signal wiring shall be color coded as follows:
AC Supply: DC Supply Signal Pair Signal Triad
Phase – Black Positive – Red or
red sleeve over any color except green
Positive – Black Positive – Black
Neutral – White
Negative – Black or black sleeve over any color except
green
Negative – White Negative – White
Ground – Green or green with yellow trace
- - Third Wire – Red
b) Thermocouples shall be as per ANSI MC96.1.
c) Blue color insulation or jacket shall only be used for intrinsically
safe installation.
5.14.5 Splices are not permitted in wiring. When wiring must be extended,
connections shall be made via terminal blocks.
5.14.6 Wiring connections shall be made to channel (rail) mounted terminal
blocks. These terminal blocks shall have tubular box clamp connector
and compression bar or yoke for wire termination. More than two
connections per terminal point are not allowed.
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5.14.7 Fused terminals shall be used for power distribution, alarm, and
shutdown systems.
5.14.8 Double Block and bleed arrangement for each one of the instruments,
grouped in the 2 out of 3 shutdown logic, shall be provided to enable
maintenance while the unit is in operation
5.14.9 Different instruments signals shall be segregated from each other and
from power wiring.
5.14.10 Cables may be routed utilizing one of two methods:
5.14.10.1 Instrument cables may be routed in conduits. The conduit
installation shall be in accordance with NFPA 70.
5.14.10.2 Armored cables may be routed on trays. For this option, the
following guidelines shall be followed:
a) The armored cable shall be suitable for the area
classification where the packaged unit is installed
(e.g., ITC, PLTC, MC, etc.).
b) The armored cables shall be routed on aluminum or
stainless channel trays. Galvanized steel trays are not
acceptable.
c) The cable armor shall be either steel wire armor or
interlocked metallic armor.
d) The trays shall be elevated and shall not be mounted
to the skid base plate unless protected by grating.
e) Tray ends are bent to avoid having sharp edges.
f) The glands at both ends of the armored cable shall be
certified flameproof (EExd) gland. Where sealing is
required by NFPA 70, the gland shall be certified
(EExd) with a compound barrier seal (e.g., CMP
Protex 2000 - PX2K).
5.14.11 JB shall be 316 series SS and be IEC 60529 type IP66 or NEMA
250/NEMA ICS type 4X and shall meet the segregation requirements
of paragraph 5.18.9.
5.14.12 Instruments and JBs shall have permanently attached engraved
phoenolic / laminate or plastic nameplates, showing tag numbers.
Phoenolic nameplates shall be installed with two stainless steel screws.
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5.14.13 All packaged unit wiring, intended for interface with plant wiring
and/or control package, shall be terminated in junction boxes.
5.14.14 Interconnecting wires between skid mounted components, between
skid mounted instruments and the skid termination panel, and between
skid termination panels and control system panels shall be tagged.
Each tag shall identify the device to which the opposite end of the wire
is connected. Heat shrink or ferrule type wire tags with permanently
embossed identification markings shall be used.
5.15 Electrical System
5.15.1 The electrical equipment shall comply with the electrical area
classification requirements designated in the Purchase Order or on the
approved electrical area classification drawing.
5.15.2 Batteries
5.15.2.1 Batteries supplying power for the DC auxiliary system and
turbine control power shall be located in a separate
ventilated building or compartment, adjacent to the turbine
control compartment in accordance to paragraph 5.18.7.
5.15.2.2 Batteries shall be suitable for site conditions and sized by
the GT Vendor to ensure proper operation and safe GT unit
shutdown.
5.15.2.3 The batteries shall be of the industrial type and capable of
supplying the required stand by power for at least ten (10)
continuous hours.
5.15.2.4 Vendor provided batteries and battery chargers shall be of
the manufacturer's proven standard design. Valve regulated
batteries are subject to pre-approval by the Chairman, Gas
Turbines & Diesel Engines Standards Committee,
Consulting Services Department. The vendor shall
demonstrate prior experience.
5.15.3 Provision for grounding the skid structure shall be made at diagonally
opposite corners. The skid structure shall be designed to accommodate
two-hole compression connector, for (2/0 AWG) copper conductor, at
each corner.
5.15.4 Motors
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5.12.4.1 Name plate rating for 480V and 4160V power supply shall
be 460V and 4000V respectively.
5.12.4.2 Motors shall meet the criteria for class F insulation, with an
allowable temperature rise, above ambient temperature of
50°C (122°F), to not exceed that listed for Class B.
5.16 Protection Systems
The combustion gas turbine unit shall be provided with the following protection
systems.
5.16.1 Overspeed Protection
5.16.1.1 The overspeed system shall have redundancy. A minimum
of one electric (electronic) and one mechanical trip devices
per shaft shall be provided.
5.16.1.2 A totally electronic system may be accepted, however, a
fully redundant system with three shaft probes and two out
of three voting logic shall be provided.
5.16.1.3 For multiple shaft units, each shaft shall have its own
overspeed trip protection.
5.16.1.4 The trip system shall allow on-line testing without
overspeeding the turbine (simulation).
5.16.1.5 A load coupling failure shall not result in a turbine speed
increase beyond the specified overspeed limit.
5.16.1.6 Alarm and trip speeds shall be specified by the Manufacturer.
5.16.2 Over-Temperature Protection
5.16.2.1 A minimum of six thermocouples shall be placed
circumferentially in the turbine exhaust gas stream to
measure exhaust gas temperatures. Alarm and trip
temperature settings for the average and spread exhaust
temperatures from the thermocouples shall be provided by
the Vendor.
5.16.2.2 Over temperature protection may use the same
thermocouples instrumentation used for the turbine
temperature control.
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5.16.2.3 Heavy industrial turbines shall have a minimum of two
thermocouples for each turbine disk cavity, where feasible.
Alarm settings for the maximum allowable disk cavity
temperatures shall be provided by the Vendor.
5.16.2.4 Aero-derivative engines shall have, as a minimum, two disk
cavity thermocouples downstream of the last turbine wheel.
5.16.3 Fire Protection
5.16.3.1 The fire detection and fighting systems shall be in
accordance to NFPA 72 and NFPA 12, respectively.
Additional means of detection, such as optical, are
acceptable. The fire protection system shall provide
coverage to the gas turbine and the driven load enclosures
(e.g., the generator enclosure, if Vendor's standard). The
protection system shall consist of a fire detection system,
fire suppression system, and for gas fueled units, a gas
detection system.
5.16.3.2 The fire extinguishing medium shall be Carbon Dioxide
(CO2). Carbon dioxide cylinders shall be stored in a
separate cabinet for outdoor applications, close to the
turbine. A device to determine if the cylinders are full shall
be supplied. A common one 100% uninstalled spare agent
cylinders shall be provided per site.
5.16.3.3 Audible and visual warning devices shall be installed inside
and outside, two each side of the GT walk-in enclosure, to
be activated 30 seconds prior to any discharge of CO2 into
the area.
5.16.3.4 The color-coding for the CO2 pre-discharge visual alarms or
beacons shall have a different distinctive color than that for
gas detection.
5.16.3.5 Lock-out devices to disarm the CO2 system when personnel
are present shall be installed unless the omission is
approved by the Chief Fire Prevention Engineer. The
control system shall display an alarm indicating a disabled
firefighting system when it is locked out.
5.16.3.6 Air-moving power and fire dampers in the ventilation
system shall shutdown upon system actuation.
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5.16.3.7 Appropriate warning signs shall be affixed in noticeable
locations inside/outside all protected CGT's compartments
and outside each entrance to CO2 cylinders storage room in
accordance with NFPA 12.
5.16.4 Gas and Hydrogen Sulfide Detection System:
5.16.4.1 Gas detection system inside the gas turbine compartment
shall be provided. Manufacturer's standard detectors are
acceptable with the exception of electrochemical detectors.
Set points shall be per the Manufacturers' standard, but in
no case shall be higher than the following levels:
Critical (High-high) alarm 50% Lower Explosive Limit (LEL)
Warning (High) alarm 25% Lower Explosive Limit (LEL)
5.16.4.2 If sour gas is used as the primary or the alternate fuel, H2S
detectors shall be installed in addition to the combustible
gas detectors. Set points shall be per manufacturers'
standard, but in no case shall be higher than the following
levels:
Critical (High-high) alarm 50 PPM Hydrogen Sulfide
Warning (High) alarm 20 PPM Hydrogen Sulfide
5.16.4.3 The gas and hydrogen sulfide detection system shall be
capable of initiating a gas turbine unit trip using a two out
of two voting system logic.
5.16.4.4 When heavy fuel gas is used, proper ventilation and gas
detectors shall be installed to facilitate gas detection and
discharge in case of a leak.
5.16.4.5 Audible and visual gas and Hydrogen Sulfide, when
applicable, detection alarms shall be installed outside of the
turbine compartment on each side. The length of the
complete train shall be considered to define the number and
locations of the alarms to ensure proper area coverage.
5.16.4.5 H2S and LEL beacon colors shall be blue and red
respectively.
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5.17 Emissions
5.17.1 Equipment noise levels shall be less than 85 dB(A) at a distance of one
meter from the unit at 1.5 meter height above ground. The Vendor
shall advise whether acoustic treatment will be required to meet this
noise requirement. The need for acoustic treatment shall be
determined after review of the plant requirements.
5.17.2 Acceptable exceptions to noise limits in 5.17.1 include those emitting
from the unit inlet filtration air-pulse system, by-pass operations,
bleed-valves, unit trips, start/shut down, transitory conditions, fuel
switch-over, no load condition, areas within enclosures, emergency
sirens, alarms, and loudspeakers.
5.17.3 Exhaust Emission levels for the full expected operating range shall be
provided for the proposed gas turbine units. Emission levels shall not
exceed the limits specified in the table below across the full operating
range identified in the data sheets or the Purchase Order.
Combustion Gas Turbines (CGTs)
Emission Requirements for Proposed Unit Primary Fuel
Within The Royal
Commission Areas Refer to the Royal Commission environmental standards
Outside The Royal
Commission Areas
Nitrogen Oxides (NOx)
@ 15% O2 <60 ppmvd
Sulfur Dioxide (SO2)
Any emission control will be
based on Ambient Air Quality
Surveillance (AAQS) compliance
5.17.4 The proposed gas turbine low emission system shall have been
performing satisfactorily in continuous service for a minimum of two
(2) years in at least two units similar to the proposed one.
5.17.5 The vendor shall be responsible for final tuning to the agreed emission
levels, start up, and commissioning of the emission controlled systems
for the total operating range of the unit.
5.17.6 Steam or water injection for emission control is not acceptable.
5.18 Control Cab
5.18.1 The cab shall be positively pressurized and equipped with 2x100%
fully segregated HVAC and pressurizing systems.
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5.18.2 False ceilings shall not be used in the control cab.
5.18.3 All requirements stated in this SAMSS shall apply on the control cab
(e.g., electrical installation, wiring).
5.18.4 The control cab shall be made of non-combustible contruction and
finishing.
5.18.5 Smoke detectors, two below the floor and two to the ceiling, shall be
installed per NFPA requirements.
5.18.6 The control cab shall be grounded.
5.18.7 All doors shall be equipped with panic bars..
5.18.8 Battery Rooms
5.18.8.1 Flooded type batteries shall be installed in concrete
construction room in accordance with Saudi Aramco
Engineering Standards (SAES) and requirements (e.g., eye
wash, safety equipments, etc.).
5.18.8.2 Regulated Valve Batteries (VRLA) shall be placed in a
separate room. It shall be in accordance with the control
cab requirements of this SAMSS and the following:
5.18.8.2.1 Battery room floor shall be covered with an
electrolyte (acid or alkali) resistant, durable,
antistatic and slip-resistant surface overall, to a
height 100 mm on each wall.
5.18.8.2.2 Battery rooms shall be provided with an
addressable spot-type smoke detection system.
5.18.8.2.3 Battery rooms shall be vented to the outside air
by forced ventilation to prevent accumulation
of hydrogen. The ventilation system is
determined such that the hydrogen
concentration shall be limited to less than 1% of
the total air volume of the battery room.
5.18.8.2.4 The ventilation system shall be 100% redundant
and based on one complete air change every
three (3) hours. Only direct driven exhaust fans
shall be used.
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5.18.8.2.5 Air-pressure measuring device, such that
ventilation insufficient to the 1% hydrogen
limit will cause the high-rate charge to stop and
alarm is displayed in the control system.
5.18.8.2.6 Doors shall open outward toward the outside of
the cab and fitted with door closers. Doors
between battery room and other rooms are not
permitted.
5.18.8.2.7 Inlets of air-conditioning shall be no higher
than the top of the battery cell and the outlets
(exhaust) at the highest level in the room.
Return air-conditioning ducts from battery
rooms shall be prohibited.
5.18.8.2.8 Working space of at least 1 meter shall be
provided in front of each battery rack.
5.18.8.2.9 Lighting fixtures shall be vapor tight and
installed at least 300 mm below the finished
ceiling to allow hydrogen dispersion past the
fixture.
5.19 Baseplates
5.19.1 A baseplate shall be required on all packaged units. A single baseplate
to accommodate the turbine, accessory and auxiliary equipment, driven
equipment, gear unit, lube oil system, and instrumentation panels is
preferred. However, baseplates over 12 m (40 ft) long may be split
into bolted and doweled sections to be assembled at the site.
Soleplates are acceptable only for very large gas turbine units which
must be shipped in sections for site assembly.
5.19.2 The Vendor shall provide the necessary features or material for
equipment leveling, including leveling shims if required. The leveling
material shall be 316L Stainless Steel. If shims are required, the
Vendor shall provide packs 3 mm to 13 mm (0.125 in to 0.5 in) thick.
5.19.3 Vent and drain piping and valves, manifolded and brought to a skid
edge flange RF type in accordance with ASME B16.5 specification.
5.20 Access Structure
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5.20.1 Grating shall be in accordance with PIP STF05530. Railings shall be
in accordance with PIP STF05520 and STF05521. Stairs shall be in
accordance with PIP STF05511.
5.20.2 Ladders and cages shall be in accordance with PIP STF05501.
However, fixed ladders shall be of the side step design, except on tanks
under 3 meters high where step-through ladders may be used.
5.20.3 The above mentioned PIPs may give solutions to certain types, if such
a case is encountered, the type and its solution shall be followed.
5.21 Structures
5.21.1 All structural and supporting materials, except ASTM A193, ASTM
A194, ASTM A490 or ASTM A490M bolts, and crane rails, shall be
galvanized, unless painting is specified in the Contract Documents.
Steel embedded in concrete (including ASTM A36, ASTM A307 and
ASTM F1554 anchor bolts) shall be hot-dip galvanized. Zinc plating
is not acceptable.
5.21.2 Galvanizing of steel shapes, washers, plates and hardware shall be in
accordance with the following ASTM specifications:
a) Steel shapes and plates - ASTM A123
b) ASTM A325 Type 1 or ASTM A325M Type 1 bolts and
corresponding nuts and washers -ASTM B695 (or ASTM A153 /
ASTM A153M when approved by the Buyer)
c) ASTM A36 / ASTM A36M threaded bar or ASTM A307 bolts
and corresponding nuts and washers - ASTM A153 / ASTM
A153M or ASTM B695
d) All bolts, nuts, and washers shall meet required mechanical
properties after galvanizing.
5.22 Anchor Bolts
5.22.1 Anchor bolts shall be in compliance with Standard Drawing
AB-036322 (The AB-036322 requirement of SAES-Q-005 shall be
considered inapplicable for anchor bolts). It is the responsibility of the
foundation design engineer to verify the capacity of any vendor
furnished or detailed anchor bolts.
5.22.2 Equipment shall be installed on mounting plate(s), and the direct
attachment of equipment feet to the foundation using the anchor bolts
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shall not be permitted. Mounting plates shall be of sufficient strength
and rigidity to transfer the applied forces to the foundation.
5.22.3 Anchor bolts and embedded items shall be set accurately, using
templates provided by the equipment manufacturer within the
tolerances specified in the AISC Section 7.5, Code of Standard
Practice, unless specified otherwise on the vendor drawings.
5.22.4 The design of anchor bolts shall be in accordance with the
requirements of Appendix D of ACI 318.
5.22.5 The minimum anchor bolt diameter shall be 20 mm (¾"), except when
specified otherwise by the vendor for small equipment or for the
anchorage of small miscellaneous steel items such as; ladder supports,
small piping supports, handrail anchorage, stair stringers, small
platforms, etc.
5.22.6 Anchor bolts subject to uplift or vibration shall be equipped with an
additional nut to serve as a lock nut, to ensure against loosening.
5.22.7 Minimum clear distance from anchor bolts or anchor bolt sleeves to
edge of concrete shall be 100 mm. Metallic sleeves are not allowed
and anchor bolts shall not be in contact with reinforcing steel.
5.22.8 Anchor bolts shall have 3 mm as a corrosion allowance in addition to
the coating required by the Standard Drawing AB-036322.
5.22.9 Post-installed anchor bolts shall not be used for new construction
without prior written approval. Approval request will only be
considered for chemical anchor bolts that are less than 20 mm (¾")
which are for use as indicted in paragraph 5.22.5. These requests shall
be submitted through the Company or Buyer Representative for review
and approval by the Chairman, Gas Turbines & Diesel Engines
Standards Committee, Consulting Services Department. When
approved for use, the post-installed bolts shall be designed per ACI
318, Appendix D and in strict compliance with the manufacturer's
recommendations.
5.22.10 Unless otherwise specified in the PO, anchor bolts and templates shall
be made available for delivery six months before the first portion of the
first equipment delivery date.
5.23 Dynamics
The turbine Manufacturer shall be responsible for providing a lateral critical
speed and unbalance response analysis for each of the train components, and a
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torsional analysis for the complete train. The analysis shall be submitted
through the Company or Buyer Representative for information to the Chairman,
Gas Turbines & Diesel Engines Standards Committee, Consulting Services
Department.
5.24 Materials
Materials of construction of the gas turbine unit shall be Manufacturer's standard
for the specified operating conditions, except as required by this SAMSS, the
Data Sheets or specified in the Purchase Order.
6 Inspection
Inspection during manufacturing shall be in accordance with the Vendor's procedures
with the exception of components required to satisfy special material requirements and
safety procedures detailed in this Specification, the Purchase Order and the minutes of
bid clarification and pre-award meetings. Buyer's inspection of the equipment shall be
in accordance with the Form 175-325501 through 325519, Inspection Requirements,
corresponding to the particular equipment and as specified in the Purchase Order.
7 Testing
7.1 Hydrostatic Tests
The Vendor shall identify in the proposal which components are tested
hydrostatically. Testing, when identified, shall be in accordance with test
procedures and acceptance criteria of API STD 616.
7.2 Mechanical Running Test
7.2.1 The gas turbine unit mechanical running test is required to verify
mechanical integrity, and shall be performed, at the manufacturer's
shop, unless otherwise approved by the Chairman, Gas Turbines &
Diesel Engines Standards Committee, Consulting Services
Department.
7.2.2 Test procedures and acceptance criteria shall be based on API STD 616
for mechanical drive units, and on Manufacturer standard's for power
generating units. The test shall be conducted at full speed and no load
for a minimum of 4 hours total duration, and it should include testing
of the shaft overspeed trip functionality.
The final testing procedure, including Vendor's proposed standard test
procedures and acceptance criteria shall be mutually agreed upon by
Vendor and Buyer and approved by the Chairman, Gas Turbines &
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Issue Date: 1 December 2007
Next Planned Update: 30 November 2012 Combustion Gas Turbines
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Diesel Engines Standards Committee, Consulting Services
Department.
7.2.3 The Vendor shall provide the results of the mechanical running test.
Dismantling of the unit is required only in the event of an
unsatisfactory test results.
7.3 Electric/Electronic instruments and Control System Tests
7.3.1 Functional test of all electronic instruments after testing for short
circuit, cable continuity, ground insulation with a “megger”, and
ground faults.
7.3.2 Functional test of all electronic control loop verifying a proper
response to simulated input signals. The functional test shall also
include, but not limited to, wiring point to point check, insulation and
dielectric test, earthing check, power destribution check, I/O signals
check and cross signal check, communcation links, sub-system check,
and softwear validation test.
7.4 Emission Test
Source emission testing or stack testing shall be performed on site within 180
days from the date of initial startup. To demonstrate compliance with applicable
source emission requirements, stack tests shall be conducted as per U.S. EPA
recommended methods. Other methods may also be acceptable; however,
approval must be obtained from EPD prior to commencement of the test(s). A
written test report shall be provided to EPD within 60 days thereafter
summarizing the results of the stack test.
7.5 Fire Extinguishing System Test
The CO2 Extinguishing System shall be required to pass a total flooding
performance field test, witnessed by the Chief Fire Prevention Engineer and the
General Supervisor, P&TS Div., Fire Protection Department or their
representatives, prior to mechanical acceptance sign-off. The test shall
demonstrate a full discharge of entire design quantity of CO2 through system
piping to verify that CO2 is discharged into the protected equipment and that the
CO2/O2 concentration is achieved and maintained for the period of time required
by the design specifications, and that all pressure operated devices function as
intended. The commissioning and testing procedures shall be submitted to the
Chief Fire Prevention Engineer or his representative prior to the time of request
to inspect for mechanical completion.
7.6 Sound Level Test
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Document Responsibility: Gas Turbines & Diesel Engines 32-SAMSS-100
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Next Planned Update: 30 November 2012 Combustion Gas Turbines
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The noise level test shall be performed on site to meet the requirements of
paragraphs 5.17.1 and 5.17.2. The proponent shall contact EPD to request noise
level testing during the commissioning process, prior to approval of the
Mechanical Completion Certificate (MCC).
7.7 Additional Optional Test
The vendor shall include a proposal for an optional gas turbine performance test
to be considered for inclusion in the Purchase Order per the following criteria:
The machine shall be performance tested on site in accordance with the ASME
PTC 1, ASME PTC 22 (or ASME modified), and ASME PTC 4.4 (COGEN
units). The test procedure shall be agreed upon by the Manufacturer and the
Chairman, Gas Turbines & Diesel Engines Standards Committee, Consulting
Services Department. Test shall demonstrate the guaranteed power and heat rate
for simple cycle units. The test shall also demonstrate the guaranteed exhaust
temperature and flow for cogeneration units.
The turbine manufacturer shall submit a report on the unit site performance
arrangement with all the required details. This report shall include all protective
settings and the necessary curves to define actual site performance.
7.8 Upon the completion of all required tests, the gas turbine rotor(s) shall be axially
and radially locked for shipment. Such arrangement will help in minimizing the
chance of any impact damage on bearings that may result during the on-road
transportation of the gas turbine unit(s).
Revision Summary
1 December 2007 Major revision.
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Document Responsibility: Gas Turbines & Diesel Engines 32-SAMSS-100
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Next Planned Update: 30 November 2012 Combustion Gas Turbines
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Appendix I – Definitions
Base Load: The Vendor's defined output load that the gas turbine is required to produce at site rated conditions
while achieving an operating life of over 20 years and the OEM recommended Time Between Overhaul (TBO).
Design Condition: The point at which usual operation is expected and optimum efficiency is desired. This point
is usually the point at which the vendor certifies that the heat rate is within the tolerances stated in this
specification. Parameters used to determine the normal operating point including speed, site conditions,
emissions, and fuel composition.
Island Mode Operation: When the gas turbine driven generator(s) is operating alone disconnected from the main
utility grid (SEC).
Life Cycle Cost (LCC): LCC is the equipment Life Cycle Cost analysis to determine cost of equipment
acquisition and operation for a 20 years basis and it typically include: initial equipment cost, maintenance, and
operational costs.
Minimum allowable Temperature: The lowest temperature for which the manufacturer has designed the
equipment (or any part to which the term is referred).
Minimum Site Temperature: The minimum recorded site ambient temperature as identified in the data sheets.
Operating Range: The load and/or speed ranges that the unit is expected to be operated within, at the site
expected conditions.
Overspeed limit: The maximum speed limit that the shaft are permitted to reach safely.
Peak Load: The power output when firing at a temperature above base load firing temperature
as specified by the Manufacturer. Peak load operation capability is intended only for limited or
emergency use.
Summer Dry Bulb Temperature at 1.0% : A dry bulb temperature that has been equaled or
exceeded by 1% (30 hours) of the total hours during the months of June through September.
Site Rated Power: The output shaft power developed by the gas turbine when it is operated at site rated: firing
temperature, speed, inlet air temperature, minimum inlet pressure, auxiliary system losses including inlet and
exhaust duct losses, exhaust pressure, and normal fuel composition. [Net shaft horsepower (HP) for mechanical
drive units, or net generator output in MW for power generation units].
Site Rated Inlet Temperature: The site's ambient temperature as identified in the data sheets, and used for
determining the site rated power.
Site Rated Speed: The rotational speed required by the unit to achieve the Site Rated Power. This speed should
be equal to or close to the normal design speed corresponding to the maximum efficiency point specified by the
Manufacturer.
Site Rated Firing Temperature: The turbine inlet total temperature, measured at a location immediately
upstream of the first-stage turbine nozzles, required to meet site rated power conditions.
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Document Responsibility: Gas Turbines & Diesel Engines 32-SAMSS-100
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Next Planned Update: 30 November 2012 Combustion Gas Turbines
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Wobbe (gas) Index: The Wobbe index is a gauge of the OEM allowable range of change in heating value. It is
the ratio of the Lower Heating Value (LHV) of the fuel gas divided by the square root of the product of relative
density (with respect to air at ISO conditions) and the absolute temperature, T, of the fuel gas:
5.0)( TG
LHVW
G is gas specific gravity