Reliance Industries Limited
RIL - OT KGD6
Pipe Stress Analysis & Pipe Supports Design Criteria
OTBC-B00-31070484-PPL-0001
1.0
INTRODUCTION ......................................................................................................... 3
2.0
APPLICABLE STANDARDS AND PROCEDURES ..................................................... 4
2.1
2.2
2.3
2.4
3.0
STRESS ANALYSIS.................................................................................................... 5
3.1
3.2
3.3
3.4
3.5
3.6
3.7
3.8
4.0
Document Precedence .................................................................................... 4
Industry Codes or Regulations ......................................................................... 4
Project Specifications ....................................................................................... 5
Definition of Terms ........................................................................................... 5
Methodology for Pipe Stress Analysis .............................................................. 5
Design Consideration ....................................................................................... 6
The Selection of Stress Critical Lines ............................................................... 12
Non-Critical Lines............................................................................................. 14
Stress Analysis Documentation........................................................................ 14
Pipe Stress Design Philosophy ........................................................................ 14
Caeser CFG (Configuration File) and Unit file .................................................. 16
Attachments ..................................................................................................... 16
PIPE SUPPORTS ....................................................................................................... 16
4.1
4.2
4.3
4.4
4.5
4.6
4.7
4.8
Intent................................................................................................................ 16
Guidelines for all Supports ............................................................................... 16
Interface Requirements with Civil Department ................................................. 16
General Design Requirements ......................................................................... 17
Materials of Construction / Standards .............................................................. 19
Pipe Shoes, Cradles and Attachments ............................................................. 19
Spring Supports ............................................................................................... 21
Sleepers and Grade Piers for Supports............................................................ 22
Page 2 of 29
Reliance Industries Limited
RIL - OT KGD6
1.0
Pipe Stress Analysis & Pipe Supports Design Criteria
OTBC-B00-31070484-PPL-0001
INTRODUCTION
Reliance Industries, Ltd. (RIL) is receiving gas from the Block known as Block KG-DWN98/3 (normally referred to as Block KG-D6) which is located in the Krishna Godavari Basin,
Bay of Bengal off the East coast of India. The gas field area expands over 7500 km2 and
is located 40km and 60 km south east of Kakinada. The Gas Field lies in water depths
ranging between 400 meters in the northwest and over 2,700 meters in the southeast.
RIL is producing gas from two discoveries, D1 and D3. Production from subsea wells is
transported to the Deep Water Pipeline End Manifold (DWPLEM) via subsea manifolds.
Two 24” deep water pipelines deliver the well fluids from the DWPLEM to the Control Riser
Platform (CRP) located in 100 meter water depth. The CRP serves as a hub for receiving
production from the current phase of development and future gas fields.
RIL is also operating the D26 (also known as the MA field) where oil and associated gas is
produced from a FPSO. The associated gas produced at FPSO is compressed,
dehydrated and then transported to the CRP via one 24” pipeline. The piping distribution
arrangement on CRP allows transporting of MA gas either after comingling with D1/D3 gas
or independently to the OT.
Three 24” shallow water / on land pipelines transport the gas from the CRP to the OT.
Gas conditioning facilities have been installed at OT to meet the gas sales specification.
The OT is situated near Gadimoga village in Taliarevu Mandal, about 30 Km south of
Kakinada in East Godavari district, Andhra Pradesh, India.
The D1/D3 field operations are controlled and monitored from the CCR located in the OT.
The associated gas from the MA field has heavy hydrocarbon fractions which are
recovered as condensate at the OT Slug Catcher. Dedicated condensate stabilization,
storage and truck loading facilities are installed at the OT.
The gas conditioned in OT is metered and delivered to RGTIL for onward transportation to
the consumers through on land cross country East/West pipelines (EWPL). Multiple
pipeline compressor stations have been built along the EWPL to boost the gas pressure.
The first compressor station (CS-01) is located next to OT boundary and immediately
downstream of the custody transfer metering facility at OT. The compressor stations
including CS-01 are operated by RGTIL. However, CS-01 is connected with plant DCS
system which gets information about the critical operating conditions of the CS-01 and
pipeline.
The main processing facilities and utility systems at OT are designed for continuous sales
gas production rates of 80 MMSCMD. MA gas and condensate facilities are designed for
a continuous rate of 9 MMSCMD of MA export gas and 30m3/hr of unstabilized
condensate feed.
Currently D1/D3 gas is being transported to the OT through two pipelines (GTL-1 and
GTL-2), while the third pipeline (GTL-3) is dedicated for transporting dry gas from the
FPSO of MA field. There are three pressure reducing stations (PRS) upstream of the slug
catcher to protect the OT from high pressures.
There are three slug catchers which are designed for 45 MMSCMD. The slug catchers
separate the rich MEG from the gas and to catch the liquid slugs generated during
production ramp up. D1/D3 gas is being processed in slug catcher 1 and 2 while slug
catcher 3 is used for MA gas.
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Reliance Industries Limited
RIL - OT KGD6
Pipe Stress Analysis & Pipe Supports Design Criteria
OTBC-B00-31070484-PPL-0001
Tie-in points have been left at all of the required locations to allow for additional modules
to be added on later date as required. Also suitable space has been allowed on the plot
plan and equipment layout to install future modules.
As the reservoir pressure depletes, gas compression is required to deliver the gas at
specified suction pressure & temperature to CS-01 compression facility. Considering the
long cycle time for installing such facility, and long delivery of critical equipment like gas
compressors, RIL intends to start work on the requirements at the earliest so that facilities
can be designed and installed in a timely manner. In addition, RIL intends to develop
other gas discoveries such as R-Cluster and Satellites; and commence work for
integration of these discoveries with the existing facilities at OT.
2.0
APPLICABLE STANDARDS AND PROCEDURES
2.1
Document Precedence
Any conflicts between requirements of this specification, related contract
documents, datasheets, international standards, code of practice and the contract
shall be referred to the Company for clarification. Where conflicts occurs the order
of precedence shall be, unless otherwise agreed:
a)
b)
c)
d)
e)
f)
Local Regulatory and Statutory requirements
Datasheets (where applicable) and relevant drawings
This Specification
Project Specifications
Indian Codes and Standards
International Codes and Standards
Within each category above, the most stringent requirement shall apply.
2.2
Industry Codes or Regulations
American Petroleum Institute (API)
API 610
Centrifugal Pumps for General Refinery Services
API 616
Gas Turbine for Petroleum, Chemical & Gas Industry services
API 617
Centrifugal Compressors for General refinery services
API 660
Shell and Tube Heat Exchangers for General Refinery Services
API 661
Air-Cooled Heat Exchangers for General Services
API 674
Positive Displacement - Reciprocating Pumps
American Society of Mechanical Engineers (ASME)
ASME B 31.3
Process Piping 2008
ASME B 31.8
Gas Transmission and Distribution Piping Systems 2007 (Rev.
Nov 30, 2007)
ASME B16.5
Steel Pipe Flanges and Flanged Fittings
ASME B16.47
Large Diameter Steel Flanges
ASME Boiler & Pressure Vessel Code
Section II
Ferrous and Non-ferrous Material Specifications
Section IX
Welding and Brazing Qualifications
ASME Sec.VIII, Div.I Boiler and Pressure Vessel Code
UKOOA - United Kingdom Offshore Operators Association (GRE U/G Piping)
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Reliance Industries Limited
RIL - OT KGD6
Pipe Stress Analysis & Pipe Supports Design Criteria
OTBC-B00-31070484-PPL-0001
Welding Research Council
WRC Bulletin No.107 Local Stresses in Spherical and Cylindrical Shell due to
external loading
WRC Bulletin No. 297 Local Stresses in Cylindrical Shell due to external loading
2.3
Project Specifications
All drawing numbers are prefaced by (2001-KGD6-D2-PF-ON-).
OTBC-B00-31070484-MES-0702
OTBC-B00-31070484-MES-0721
OTBC-B00-31070484-MES-0718
OTBC-B00-31070484-MES-0722
OTBC-B00-31070484-MES-0723
OTBC-B00-31070484-PPL-0701
OTBC-B00-31070484-PPL-0702
OTBC-B00-31070484-PPS-0703
OTBC-B00-31070484-PPS-0706
OTBC-B00-31070484-PPS-0707
OTBC-B00-31070484-PPS-0708
OTBC-B00-31070484-CIL-0001
OTBC-B00-31070484-PRS-0724
OTMO-B00-31070484-MES-0707
OTMO-B00-31070484-MES-0708
OTMO-B00-31070484-MES-0710
2.4
3.0
Specification for Pressure Vessels
Specification for Centrifugal Compressor
API 617 Addendum
Specification
for
Air
Cooled
Heat
Exchangers
Specification for Gas Turbine API 616
Addendum
Specification for Gas Turbine Driven
Compressor Package
Piping Design Basis
Piping Material Specification
Piping Standard Details
Standard Pipe Support
Technical Specification for Pipe Supports
Technical Specification for Packaged
Equipment Piping
Civil / Structural Design Basis
General Site & Utility Data and Units of
Measurement
Specification for Shell and Tube Heat
Exchangers
Specification for API 610 Centrifugal Pumps
Specification for API 674 Reciprocating
Pumps
Definition of Terms
Buyer
Reliance Industries Limited (RIL)
Seller
Party responsible for manufacturing or supplying of equipment and/or
goods and/or materials and/or services.
STRESS ANALYSIS
3.1
Methodology for Pipe Stress Analysis
Stress Analysis of lines shall be called out to demonstrate conformance with the
engineering requirements of the piping design code (ASME B31.3 / B31.8
wherever applicable), including both pressure containment and flexibility analysis.
The flexibility analysis of lines for formal comprehensive analysis shall be done
using the 5.20 version of CAESAR II.
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Pipe Stress Analysis & Pipe Supports Design Criteria
OTBC-B00-31070484-PPL-0001
Reliance Industries Limited
RIL - OT KGD6
3.2
Design Consideration
3.2.1
Design Code
ASME B31.3 - Shall be followed for stress qualification for all the lines
except for *6 LB & 15 LB Pipe Spec.
ASME B31.8 - Shall be followed for stress qualification of 6 LB & 15 LB
Pipe Spec.
3.2.2
Ambient Temperature
The ambient minimum and maximum temperatures for design purposes
shall be taken as stated in the “General Site & Utility Data and Units of
Measurement” specification.
As per referenced specification, Table 3.1-2:
Maximum Ambient Temp = 45 ºC
Minimum Ambient Temp = 16.6 ºC
Consider Reference Installation temperature as 16.6 ºC for pipe
stress analysis.
3.2.3
Design Temperature
Design Temperature (Maximum / Minimum), as specified in line list, shall be
used for calculation, except for Part B. The following parameters shall be
checked / qualified at Design Temperature:
Thermal Stress (Expansion Stress)
Pipe Support Load
Thermal Displacement
Static Equipment Nozzle loads
3.2.4
Operating Temperature
Operating temperature, as specified in line list, shall be used for calculation.
The following parameters shall be checked / qualified at Operating
Temperature:
Thermal Stress (Expansion Stress)
Pipe Support Load
Thermal Displacement
All Equipment Nozzle loads
3.2.5
Design Pressure
Design pressure as specified in line list shall be used for sustained stress
qualification.
3.2.6
Steam Out Temperature
Steam out condition per line list.
3.2.7
Fire Case
Fire case is not applicable for this project.
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Reliance Industries Limited
RIL - OT KGD6
3.2.8
Foundation Settlement
Differential settlement for all equipment and piping supports on piled
foundation shall be considered per the values provided by Civil/Structural
Group based on calculations.
At UG/AG interface connection, settlement will be considered.
3.2.9
Friction Factor
The following coefficient of friction shall be used at support locations:
Surface
Steel to Steel
PTFE to PTFE
PTFE to SS
Steel to Concrete
Graphite to Graphite
Friction Coefficient
0.3
0.08
0.1
0.5
0.15
PTFE shall be used only up to Design Temperature of 1200 ºC. For a
temperature of more than 1200 ºC, graphite shall be used as an antifriction
pad.
3.2.10 External Loading
3.2.10.1 Wind Load
Wind load analysis shall be carried out to IS 875 (Part 3 – 1987)
on exposed lines as indicated below. The analysis shall include
a 3-sec GUST wind velocity of 60 m/s applied at an elevation of
10 m and above from the datum level. Effect of wind shielding
from other pipe work and structures can be considered as
appropriate.
Wind loads are to be considered as a minimum for exposed lines
greater than or equal to 10” diameter, including insulation
thickness.
Based on Indian Standard IS: 875 (Part 3)
Basic Wind Speed: Vb = 60m/s (working wind speed)
Probability Factor: K1 = 1.07 for process structures
Terrain Category Factor: K2 = varies as per IS: 875.
classified as Terrain Category 2
Topography Factor:
Site
Site
K3 = 1.0 Negligible Influence of Local
Wind loads shall be combined with “Operating Temperature“, and
the following parameters shall be checked / qualified:
Occasional Stress (Sustained + Wind)
Support Loads.
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Reliance Industries Limited
RIL - OT KGD6
Pipe Stress Analysis & Pipe Supports Design Criteria
OTBC-B00-31070484-PPL-0001
3.2.10.2 Seismic (Earthquake) Loads
Seismic loads shall be analyzed by Equivalent Static Method.
The earthquake load magnitude are given in terms of the
“Gravitational Acceleration constant (g)”.
Seismic load analysis is to be performed on all stress critical
lines, seismic load analysis to be performed as per the relevant
piping code. Seismic design forces shall be in accordance with
IS 1893, with a zone factor of Z = 0.22. Values for acceleration
with respect to gravity (where g = 9.8065m/s2) are to be
calculated using the parameters defined by the Civil / Structural
Design Basis document.
Refer to Annexure A for the Gravitational Acceleration factor (g).
To determine loads on pipes, the following parameters shall be
adopted based on the type of superstructure that supports the
pipe.
Importance Factor
I = 1.75
Response reduction factor:
R = 4.0 – for pipe work on structural steel
R = 5.0 – for pipe work on RCC structures
Spectral acceleration coefficient Sa / g = 2.5 corrected for:
2% damping – for pipe work on structural steel
5% damping – for pipe work on RCC structure
The Gravitational acceleration factor (g) for all the pipes on
concrete structure shall be based on the factors defined for RCC
structure. For all the remaining piping, the “g” factor shall be
based on structural steel factor.
Seismic (earthquake) loads shall be combined with “Design
Temperature“, and following parameters shall be checked /
qualified:
Occasional Stress (Sustained + Seismic)
Support Loads
3.2.10.3 PSV Discharge Force
Loading caused on piping due to safety valve discharge forces
shall be included in the pipe stress analysis and supports shall be
located and designed accordingly.
The PSV discharge reaction force shall be calculated per APIRP520.
For the PSV‟s discharging to atmosphere (open system) it is
recommended that maximum dynamic load factor (DLF) of 2.0 to
be multiplied to static reaction force.
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Reliance Industries Limited
RIL - OT KGD6
Pipe Stress Analysis & Pipe Supports Design Criteria
OTBC-B00-31070484-PPL-0001
PSV‟s relieving under steady state flow condition into a closed
system do not transfer large forces and bending moment as that
of Open system. However, at the point of sudden expansion in
discharge piping, there will be inlet piping reaction force. To
avoid any vibration to the piping system due to sudden
expansion, the piping shall be properly restrained. To calculate
the reaction force for closed system, it is recommended that a
maximum dynamic load factor (DLF) of 1.25 be multiplied to
static reaction force.
The PSV reaction force shall be analyzed as “occasional load”.
Two occasional loads should not be considered as acting
concurrently.
Two-phase flow lines subject to slugging:
Slug flow is a condition of bolus liquid flow. Such a flow may be
created by a sudden flow of high velocity gas over the surface of
a slowly moving fluid in pipe. This produces a liquid wave which
can become a slug if it crests at the top of the pipe. The impact
of this slug generates tremendous force when exerted on the
elbow. The magnitude of the impact force depends on the
velocity and density of the slug.
The slug force shall be analyzed considering as static force with
dynamic load factor (DLF) of 2.0.
The slug force shall be combined with operating temperature and
analyzed as an “occasional” case.
Flow-induced vibration studies shall be carried out for big bore
lines having large pressure drop across any valve / device.
These studies will be performed by MEC (Mustang Engineering)
or by external agency under supervision of MEC (Mustang
Engineering). Lines requiring these studies will be identified by
MEC process. Recommendations of these studies shall be taken
into consideration during stress analysis and pipe support design.
An acoustic-induced vibrations (AIV) study shall be carried out for
blow-down and flare lines. Recommendations of AIV study shall
be taken into consideration during stress analysis and pipe
support design.
3.2.11 Equipment Nozzle Load
The nozzle loads shall not exceed the requirements specified in the
applicable industry standards for that equipment, and shall also comply with
the additional equipment nozzle loads per Table 1.0. Also see design
temperature and operating temperature discussion above for computing
nozzle loads. For pressure vessels, the allowable nozzle loads are
specified in the specification for pressure vessels, 2001-KGD6-D2-PFONOTBC-B00-31070484-MES-0702, and for Shell and Tube Heat
Exchangers, within specification 2001-KGD6-D2-PF-ON-OTBC-B0031070484-MES-0707(refer to Annexure-F for allowable nozzle loads for
vessels and heat exchangers).
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Reliance Industries Limited
RIL - OT KGD6
Table 1.0 - Allowable Nozzle Loads
Equipment
Allowable Nozzle
Loads
Vendor Data Required
Centrifugal
Pumps
2 x API 610 Table II
Pump type, nozzle size*
Gas Turbines
Packaged
equipment spec for
inlet and for exhaust
vendor allowable to
be followed
Nozzle locations*
Fixed point location,
Average casing temperature
Nozzle displacements
2 x API 617
Nozzle locations*
Fixed point location, average
casing temperature
Nozzle displacements
Vendor to advise
Volume bottle nozzle size, fixed
point location, nozzle flexibility
values*
2 x API 661
*
2 x API 560
Nozzle displacements*
Appendix P, API650
Nozzle flexibility*
Centrifugal
Compressors
Reciprocating
compressors
(volume bottle
nozzle sizes)
Air cooled heat
exchangers
Furnaces / Fired
Heaters
Storage Tanks
*Vendor to provide GA drawing and allowable nozzle loads.
The situation of nozzle loads exceeding values of Annexure “F” and Table
1.0 can be resolved in either one of the following methods:
Using WRC-107 or Nozzle PRO
Seek approval from vendor
At terminal package limit locations, the package sellers to provide full
anchors and allowable terminal loads to ensure the terminal anchors are
capable of withstanding the additional affects of loads from the externally
connected piping as stated in the “Technical Specification for Packaged
Equipment”.
3.2.12 Hydro test case
A hydrotest stress qualification is to be performed using hydrotest pressure.
A separate hydrotest calculation for support loads shall be performed for
lines 10” NB and above where the specific gravity of the contents is ≤0.8.
These loads shall also be included in the spring hanger and rod support
data sheets for rod sizing.
3.2.13 Local attachments
Local attachments stresses (trunnions, etc.) shall be calculated as required
using approved company or project methods (e.g., “Kellogg Method”, or
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Reliance Industries Limited
RIL - OT KGD6
WRC Bulletin No. 107). The attachment size and any required R Pad
should be shown on the stress sketch.
For packaged equipment, company procedures shall be issued to the buyer
for review and acceptance.
3.2.14 Flange leakage calculation
Flanges shall be reviewed to ensure leakage does not occur due to the
combined effects of internal pressure and external loads. The method used
can be based on the standard charts or tables, stress software (Caesar), or
the total equivalent pressure method as per ASME III Division 1, NC-36581. The calculated total equivalent pressure should be compared with the
maximum rated pressure as per ASME B16.5/B16.47. If these simplified
methods predict that leakage could occur, then in-depth flange analysis is
required to ASME VIII Div. I, Appendix II. These flange leakage checks
shall be done if the following is evident:
Sustained stresses
If the flanged joint exceeds 50% of the code allowable stress, and/or
expansion stresses at the flanged joint exceeds 60% of the code allowable
stress (liberal allowable stresses shall not be used for this comparison
check).
3.2.15 Liberal allowable stress
Liberal allowable stress will be used per code (ASME B31.3). However, it
should not be used unless it is properly justified. Wherever liberal allowable
stress is used in calculation, it should be highlighted in the stress
calculation report.
3.2.16 Hot sustained stress qualification (support lift up)
Wherever in hot case (temperature) the pipe is lifting up from the support
point, these supports shall be deleted and the piping system shall be
qualified in sustained stress. If the sustained stresses are not within the
limit, pipe supports shall be reviewed or spring supports shall be used to
make the system safe.
The stress calculation number shall be same with an extension of “lift”.
3.2.17 Full expansion range
In the case of lines with design temperatures ranging from positive to
negative design temperatures, the analysis shall be done as follows:
e.g., T1 = + 100 C; T2 = -100 C; TINSTALLATION = 16.5 C.
The load cases shall be:
W+P1+T1 (OPE)
W+P1+T2 (OPE)
W+P1 (SUS)
L1-L3 (EXP)
L2-L3 (EXP)
L1-L2 (EXP)
Operating load case at T1 = + 100 C
Operating load case at T2 = - 100 C
Expansion from installation to +100 C
Expansion from installation to -100 C
Full expansion range (+100 C to -100 C)
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Pipe Stress Analysis & Pipe Supports Design Criteria
OTBC-B00-31070484-PPL-0001
3.2.18 Spring Support
Generally the use of spring supports shall be avoided. However, if
required, the spring supports shall be used to qualify the nozzle loads and
stresses.
The piping system subjected to vibration such as PSV discharge, 2-phase
flow lines, and slug prone lines, spring supports should not be used.
All-spring supports shall be programmed (C-II) designed at “Operating
Temperature”.
Spring shall be selected within economic operating range. The load shall
be at or around 50% of the range, and also have adequate margin in travel
range.
Once spring is selected by program (C-II), the spring data (cold load and
spring rate) shall be inputted as user defined in calculation, and then the
spring variation shall be checked at design or any upset condition. In any
design condition, the variation should not be more than 25%.
Spring Variation = (movement x spring rate x 100) / (Hot Load)
Preferred spring vendor for calculation is “Lisega”.
However, after
finalization of spring vendor, the stress calculations shall be updated per
final vendor information.
All spring supports on liquid lines shall be checked for Weight No Content
(WNC) case. The equipment nozzle loads and/ or stresses in the piping
system should not exceed the allowable in WNC case at installation
temperature.
All spring supports shall be checked for hydrotest condition, and hydrotest
load shall be marked in the spring support schedule.
3.3
The Selection of Stress Critical Lines
The criteria for selection of stress critical lines for comprehensive stress analysis
are as follows:
1)
All CS, AS, and SS lines 3” NB with a design temperature of 175 °C and
above, or -46 °C and below.
2)
All CS, AS, and SS lines 4” NB to 14” NB with a design temperature of 120
°C and above, or -46 °C and below.
3)
All lines 16” NB and above.
4)
Where SS = Stainless Steel; AS = Alloy Steel; CS = Carbon Steel
5)
All high alloy and non-ferrous metallic lines.
6)
All lines 2” NB and above connected to strain sensitive equipment such as
pumps, compressors, turbines and glass-lined vessels. For carbon steel
centrifugal and vertical in-line pump system with inlet lines 2-1/2” to 6” NB
with a maximum operating temperature below 65 °C, analysis is not
required. Adequate supports local to the pump nozzles must be provided to
minimize weight loads imposed on the machinery.
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Pipe Stress Analysis & Pipe Supports Design Criteria
OTBC-B00-31070484-PPL-0001
7)
Lines of sizes 2” NB and above connected to air-cooled heat exchangers,
fired heaters, waste heat boilers and glass-lined equipment.
8)
Thick walled pipe 3” NB and larger (schedule 160 pipe up to and including
24” NB or lines with a wall thickness greater than 10% of the outside
diameter).
9)
Thin walled pipe of 20” NB or over with a wall thickness of less than 1% of
the outside diameter.
10)
All pressure relief and blowdown lines 2 ”NB and larger, excluding drains.
11)
All lines from relief valves, or bursting discs. For lines connected to open
discharge relief valves, lines 2” NB and above (based on inlet diameter),
and having a set pressure of 500 kPa and above, are required to be
analyzed. Consideration is also required for closed relief systems. The
short-term forces for closed systems are to be suitably designed for,
including restraints, limiting vibration. A comprehensive stress calculation
in these instances may be required on a case by case basis. Similar to
open relief systems, only consider lines connected to closed relief valves 6”
NB and above with a set pressure of 500 kPa and above.
12)
All lines subjected to 2-phase slug flow, lines subjected to external
mechanical vibration, or lines subjected to internal forces such as pulsation
as defined on the line list.
13)
Piping 3” NB and larger connected to vessels, tanks or equipment subject
to differential settlement or any significant external displacement.
14)
All lines covered by ASME B31.3 - Section 319.4
15)
Main flare system lines.
16)
Other systems that, in the opinion of the stress engineer/package seller,
require special attention.
17)
GRE-buried underground fire water piping (by GRE piping vendor).
However, the analysis will be reviewed and approved by MEC (Mustang
Engineering).
18)
All lines which are being connected or tied into existing piping shall be
analyzed for assessing the impact on existing supports. Analysis shall be
carried out to the first anchor support, and all existing supports shall be
checked for revised loads.
19)
HDPE buried underground piping.
20)
Any lines considered as stress critical by process to be identified on line list.
21)
Piping support adequacy check for the slug force: Revised slug-induced
forces shall be calculated based on the process input related to possible
cases of slug flow for the revised operating envelop. Static equivalent load
approach shall be followed to determine / analyze the effects of slug forces
on the existing piping system. Based on the stress analysis, modifications
will be proposed to maintain the stresses within allowable limits. Scope
includes review of process gas piping from the pig receiver launcher
through HIPPS to the slug catchers (including slug catchers). Lines
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OTBC-B00-31070484-PPL-0001
requiring slug flow analysis shall be identified by MEC (Mustang
Engineering) process.
Existing piping as a part of brownfield modification shall be analyzed for revised
operating conditions to ensure that the lines are not overstressed and, if so,
revised supporting shall be designed.
3.4
Non-Critical Lines
All lines not included in 4.3 above will be considered as non-critical lines and
adequately supported and reviewed by piping design.
3.5
Stress Analysis Documentation
For all critical lines, a stress isometric shall be prepared, which shall be submitted
for review.
For packaged equipment, the seller is to submit a copy of the stress input (which
includes assumptions, load cases, materials, and restraints), and output results
(including a restraint load summary, displacement report, element forces, and a
stress summary) to the buyer for review and acceptance. A soft and hard copy in
this instance are both required.
Stress model shall include the trunnion support.
The stress sketch shall be marked clearly to show node numbering, nozzle
movements, position and type of supports, large movements (>50 mm), size of
dummy supports or attachments, restraint loads, details of springs or special
components, and special instructions regarding installation.
For all stress calculation, the following documents must be attached as a minimum:
1)
2)
3)
4)
5)
Nozzle load comparison sheet (refer to Annexure – D)
Caesar II Flange qualification
Relevant equipment drawing
All vendor data for valves, filters, strainers, etc.
PDMS stress isometrics with all the information such as node numbers,
type of supports, non-standard guide gaps, spring support details, etc.
Any assumptions made in calculation shall be clearly written with proper
justification.
Stress calculation number - The stress model / calculation shall be identified by the
major pipe number part of the stress system.
Stress calculation register - Stress calculation register shall be maintained to
indicate the progress of the stress work. At the end of project, the final stress
calculation register shall be submitted, along with all the calculations.
3.6
Pipe Stress Design Philosophy
The two main criteria which define the minimum acceptable flexibility are:
The allowable stress range in the pipe
The limiting values of the forces and moments which the pipe is permitted
to impose on the equipment to which it is connected
Page 14 of 29
Reliance Industries Limited
RIL - OT KGD6
Pipe Stress Analysis & Pipe Supports Design Criteria
OTBC-B00-31070484-PPL-0001
To achieve a satisfactory result, the Stress Engineer / Package Seller must select
one of the following:
Accept the layout on the basis of previous experience, e.g., by comparison
to a similar system. Package sellers are to provide background evidence to
support the design in this instance (including comprehensive calculations).
Accept the layout on the basis of a formal comprehensive analysis.
Centrifugal Pump Piping
Generally the pumps are arranged in two or three pump hook-up arrangements.
The stress calculations shall be done on the basis of the spare pump at ambient
temperature and operating pump(s) at design temperature. However, for nozzle
loads, the operating pump(s) shall be considered at operating temperature and not
at design temperature.
The temperature of the spare pump piping from the pump up to the block valve
shall be taken as ambient, while the temperature of the dead leg piping from the
block valve to the tee junction of the operating pump piping shall be taken as
follows:
Dead leg temperature - [Ambient + (⅓ differential between operating and ambient
temperatures)]
The load cases shall be typically built as follows:
Table 2.0 - Temperature Cases for Pump Piping (2-Pump System)
Temperature
Description
Pump Condition
Check Required
Case
Code stress
T1
Design temperature
All pumps operating
compliance only
Max. operating
Operating pump A
Nozzle load
T2
ambient & dead leg
Spare pump B
check
temperature
Max. operating
Operating pump B
Nozzle load
T3
ambient & dead leg
Spare pump A
check
temperature
Nozzle alignment check shall be done by freeing the nozzle and checking the
displacements in sustained load case (weight without contents). In the case of
spring hangers located in the vicinity of nozzles, the support shall be considered as
rigid while checking the nozzle alignments. The results shall be recorded in the
stress book. The permissible misalignment shall be within the flange bolt-up
tolerances (typically 5 mm). If the displacement is more than 5 mm, the location
of supports in the proximity of the equipment nozzle requires further review to
reduce the initial displacement when the piping is connected to the equipment.
The supports shall be located in such a manner that the piping weight should be
taken off the nozzles. This can be achieved by providing adjustable supports or
spring supports in the vicinity of the nozzles. The springs shall be sized by freeing
up the nozzle to ensure that piping weight is taken by the springs.
Rigid supports in the vicinity of pump nozzles shall be specified as adjustable
pedestal type.
Page 15 of 29
Pipe Stress Analysis & Pipe Supports Design Criteria
OTBC-B00-31070484-PPL-0001
Reliance Industries Limited
RIL - OT KGD6
Credit shall not be taken into account for any reduction of nozzle loads caused by
friction.
3.7
Caeser CFG (Configuration File) and Unit file
The Caesar II configuration set up file and unit file for this project is prepared and
attached as Annexure B.
3.8
Attachments
Annexure A
Annexure B
Annexure D
Annexure F
4.0
Earthquake calculation
Caesar CFG & Unit file
Nozzle load comparison sheet
Allowable nozzle load table for vessels and heat
exchangers
PIPE SUPPORTS
4.1
Intent
This specification enumerates basic criteria applicable to the design of pipe support
components.
This specification provides selection criteria for the Engineering Specification,
“Technical Specification for Pipe Supports”.
4.2
Guidelines for all Supports
All piping of ½” diameter and above shall have supports selected and located.
Physical pipe supports (both primary and secondary) shall be modelled in PDMS.
All supports shall be designed to satisfy the following requirements:
1)
2)
3)
4)
5)
6)
4.3
Have provisions for reasonable adjustability at the job site.
Be readily installable with usual field labor and equipment.
All threaded or equivalent adjustments shall be provided with a suitable
locking device.
All components shall be fabricated and erected so that they cannot become
disengaged by movement of the supported piping.
Support points shall be selected to optimize load distribution and weight
balance, taking into consideration available building structures to which
supports can be most readily affixed.
„T‟ supports from pavements to be minimized.
Interface Requirements with Civil Department
(Not applicable to package sellers).
Large discrete loads on concrete slabs / floors or steel structures shall be
submitted to Civil / Structural Department for design of the secondary support
structure / foundation, when they exceed the following conditions:
1)
2)
3)
Support TOS higher than 1500mm from grade
Maximum vertical load >10 kN
Maximum horizontal load >5 kN
Page 16 of 29
Reliance Industries Limited
RIL - OT KGD6
Pipe Stress Analysis & Pipe Supports Design Criteria
OTBC-B00-31070484-PPL-0001
Where there is an accumulation of horizontal loads, e.g., an anchor bay on a
piperack, these shall be tabulated by the stress engineer and submitted to the Civil
Department for sizing of columns, and bracing.
4.4
General Design Requirements
1)
2)
3)
4)
5)
6)
7)
Pipe supports span to be followed as per span chart attached OR as
proven acceptable by stress analysis.
Concentrated loading due to valves, flanges, branches, etc. must be taken
into consideration while being supported.
Lines on pipe rack / sleeper, to be provided with a resting support on every
main grid of pipe rack / sleepers as a minimum.
Vertical deflection/sag of a piping system in a horizontal run between two
adjacent supports due to sustained loading shall be limited to:
11 m for lines up to 3” NB
8 mm for lines 4” NB & above
One leg of control valve stations shall be anchored or guided and pipe legs
entering and leaving the station must be flexible enough so as not to
exceed allowable stresses in the piping and valves
Structural attachments to steel shall have sufficient bearing weld metal to
adequately support the maximum calculated load, including hydrostatic test
loading.
Shims used in the field to achieve full bearing between pipe and / or pipe
attachment and the structural steel and / or grade pier shall have sufficient
area to carry the load to the structural component.
After erection, shims must be securely welded to the structural steel
to prevent shim slippage when pipe moves during operation.
Unless the support is indicated to be a welded anchor (fixed) shims
shall not be welded to the pipe or pipe attachment.
If Shims are required to be welded to pipe shoes then they must
extend the full length and width of the shoe.
Shims whose width does not exceed the width of the supporting
structural beam shall be welded to the beam only.
8)
9)
10)
11)
12)
13)
Minimum headroom clearance of the lowest projection of any pipe support
component shall be limited to the allowable headroom clearance.
First piping support from strain sensitive / rotary equipment to be of
adjustable type.
Horizontal or vertical pipes should preferably be supported at a location of
least vertical movement.
Horizontal axial movement of a pipe in excess of 4” (100 mm) requires a
check on the length of pipe shoe being used. It is imperative that the length
of all shoes be such that the required bearing areas remain on the
supporting steel during the full anticipated movement of the line.
U-bolts can be used up to 6”NB for guiding vertical lines. As far as possible
avoid guiding of horizontal lines by U bolts.
Hanger rod supports
Page 17 of 29
Reliance Industries Limited
RIL - OT KGD6
Pipe Stress Analysis & Pipe Supports Design Criteria
OTBC-B00-31070484-PPL-0001
Use of hanger rods shall be minimized
At points of support subject to horizontal movements, rod type
hangers shall be limited in rod swing to a maximum of 4º from the
vertical
A catch beam below the pipe near to the point of support should be
provided to ensure the pipe will be supported in the event of rod
failure.
14)
15)
16)
Lines with 2-phase flow conditions (boiler blow down, etc.) shall be
supported on rigid supports unless thermal movements dictate otherwise.
Long trunnion type supports are to be avoided as far as possible and
maximum height of trunnion to be restricted to 1500mm. In the case of
trunnions longer than 1500mm, the stress engineer is to be consulted.
Supporting of uninsulated and personnel-protected insulated lines, the
following should be followed:
For thin-walled stainless steel pipes 10” NB and below, wear pad
made from parent pipe shall be provided only as shown in the
attached span tables.
For all pipes 16” NB and above, a wear pad shall be provided.
Special care also shall be taken for thin-walled pipe.
If the pipe will suffer from environmental deterioration (e.g. for
stainless steel lines which may be prone to local cell corrosion), an
isolation pad may be required.
Stainless steel and carbon steel lines expected to see below zero
degree Celsius temperatures for an extended period shall be
supported on shoes; i.e., all the HP and LP flare header and blow
down lines shall be supported on shoe.
17)
18)
19)
20)
21)
22)
23)
All lines of 30” diameter and above shall be supported on shoe /
saddle.
Reciprocating compressor piping that is prone to vibration shall be
designed so that it can be supported from grade sleepers. The span
spacing shall be calculated so as to minimize the sympathetic vibrations
between the piping and the pulsation of the compressor fluid flow. As far as
possible provide independent supports for piping at higher elevations
Locations where pipes and shoes are not to be resting on structural steel
should be clearly indicated mentioning the required minimum gap.
Pick-up supports, i.e. supporting of small diameter pipes by large diameter
pipes, are generally to be avoided. In the case of packaged equipment, the
seller shall submit the design to the seller for review and acceptance by a
stress engineer.
Guide gap to be 3 mm unless specified otherwise. Special adjustable “zero
gap” guides shall be used to protect sensitive equipment nozzles where
specified and be clearly identified on the stress isometric.
Special requirements for small bore branch connections:
Adequate care shall be taken for small bore (2” NB and below) branches
from piping. As a rule, for all lines in 600 LB and above classes, lines
Page 18 of 29
Pipe Stress Analysis & Pipe Supports Design Criteria
OTBC-B00-31070484-PPL-0001
Reliance Industries Limited
RIL - OT KGD6
having 2-phase flow and lines having pulsating flow such as
suction/discharge of reciprocating compressors and reciprocating pumps,
all small bore branches of size 2” NB and below, e.g. vents, drains, orifice
taps, pressure tapings, temperature tapings, sample connections, PSV
inlet, TRV inlet and small bore line etc. shall be provided with 2 off
stiffeners at 90° to each other from the main pipe to impart adequate
stiffness to the branch connection. The stiffeners shall be made of 6 mm
thick flats of material equivalent to the pipe material. Further, irrespective
of line rating, the stiffeners shall be provided for all orifice taps, all small
bore tappings from PSV inlet and the outlet lines and all small bore
tappings in and near control valve manifolds.
For these stiffeners, a standard piping support tag number is to be
incorporated on the Piping Isometrics by piping design group.
24)
25)
26)
27)
28)
4.5
Materials of Construction / Standards
1)
2)
3)
4)
4.6
All other lines except plastic can rest directly on steel, except as noted
above.
All relief valve tailpipes and long drain pipes discharging to grade shall be
adequately guided or otherwise restrained unless noted otherwise in the
stress isometric.
In the case of Polyethylene (PE) pipes ≤ 8”NB (OD 225mm), these shall be
continuously supported using cable ladder type supports or inverted angles,
depending on the layout, contents, and temperatures expected.
Manufacturer recommended span tables should also be sought. Heavy
fittings such as valves should be supported independently and large plastic
fittings (e.g. flanges, particularly those with metal backing rings) should be
supported on each side. Where pipes are continuously supported, flanged
connections and other protrusions should be allowed room for movement.
Lines with acoustic insulation shall be supported on acoustic isolation units
or be supported on shoes with acoustically isolated clamps.
Where a fixed attachment identified on the piping isometric is not covered
by a standard drawing, a special pipe support sketch is to be produced and
shall provide sufficient dimensional data to enable fabrication. They shall be
checked by the stress engineer for conformance to project requirements.
Materials used for pipe supports, will be shown in the pipe support
specification
IS (Indian Standard) material standards to be used.
For a description of shoes used on insulated hot piping refer to Section 4.6
below.
All attachments welded to pipes shall be of a material in accordance with
parent pipe material unless noted otherwise.
Pipe Shoes, Cradles and Attachments
Table 3.0 - Table to be used for selecting type of shoe:
Pipe
Material
Pipe
Size
Temp ºC
Type of
Support
Page 19 of 29
Shoe Type
Pipe Stress Analysis & Pipe Supports Design Criteria
OTBC-B00-31070484-PPL-0001
Reliance Industries Limited
RIL - OT KGD6
Pipe
Material
Pipe
Size
Temp ºC
Type of
Support
Shoe Type
CS
All
sizes
All
*Rest,
Guide,
Anchor
CS welded shoe
SS
All
sizes
SS
All
sizes
SS welded shoe with CS Base plate;
*Rest, Guide
150
Or CS welded shoe with SS wear pad;
Or CS clamped shoe with liner
> 150 to
300
*Rest,
Guide,
Anchor
SS welded shoe with CS base plate;
Or CS clamped shoe with liner
*For SS/CS/AS pipe, use long welded shoe at locations of anchors and at locations of large
axial pipe movement.
For all insulated lines (except personal protection lines), shoe height to be used as
follows:
Insulation tank
75 mm & below
76 mm to 125 mm inclusive
126 mm to 175 mm inclusive
Shoe Height
100 mm
150 mm
200 mm
Shoe heights may require modification to ensure that the contact surfaces on
concrete beam supports or on structural steel beam supports do not exceed 120
°C or 400 °C respectively.
1)
The reduction factor is 50°C per inch of shoe height from the outside
surface of the pipe for determining shoe heights to reduce support contact
temperatures.
2)
Shoes for sloping lines to be cut suitably to suit slope of pipe.
3)
All pipes with personal protection (PP) insulation shall be directly resting on
support structure. Insulation to be cut locally.
4)
All not traced (NT) small bore pipes (1.5” NB or less) with HC or PP
insulation shall be directly resting on support structure. Insulation is to be
cut locally.
5)
Bare pipes shall rest directly on support if the contact area temperature
does not exceed 120°C on concrete beam supports or 400°C on structural
steel beam supports, otherwise shoes of sufficient height shall be provided
such that the contact area temperature does not exceed the above
limitations.
6)
At support points for piping requiring cold insulation, 0°C and below, a
molded high density polyurethane insert and steel cradle type support shall
be provided to protect the insulation against failure during erection and
operation.
Page 20 of 29
Reliance Industries Limited
RIL - OT KGD6
4.7
Pipe Stress Analysis & Pipe Supports Design Criteria
OTBC-B00-31070484-PPL-0001
7)
Welded trunnions or lugs shall be the same material as the pipe to which
they are welded and shall be welded to the pipe by the piping fabricator
unless specified otherwise.
8)
Welding shall be in accordance with ASME B31.3 / 31.8 (Wherever
applicable)
9)
For stress relieved piping, the attachments shall be welded prior to stress
relieving pipe.
Spring Supports
1)
Spring support shall be used if the use of a rigid support would cause and
over stress in the piping or excessive equipment loading.
2)
At points of support subject to vertical movement, springs of suitable design
shall be used so that variation in supporting effect does not exceed
permissible percentages of the calculated piping load through its total
vertical travel.
3)
The amount of variation that can be tolerated shall be based on such
consideration as bending effect, control of piping elevation, allowable
terminal loading, amount of load transfer to adjacent supports, etc.
4)
The variation in supporting effect shall be generally limited to 25% of the
calculated pipe load through its total vertical movement.
5)
For all systems a greater allowance in percent load change is permissible
where the load variation in supporting effect is transferred directly to a rigid
support or terminal connection specifically designed for the resulting
loading conditions.
6)
Calculation for the variation of the support effort shall be based on the
following formula:
Variation % = (Travel) x (Spring Constant) x 100
(Operating Load)
7)
Where variable spring hangers are specified they shall be initially pre-set at
the installed load position so that the piping system is fully supported during
normal operating conditions.
8)
Constant support hangers shall be of substantial construction, with springs
and moving parts suitably covered or protected.
Each unit shall be individually shop calibrated to support the specified
operating load with provision for possible field adjustment equal to plus or
minus 10% of the operating load.
9)
10)
Load deviation shall not exceed 6% throughout the total travel range.
Components of spring supports shall be capable of adequately supporting
piping during hydrostatic test loading.
All can / bottom type spring supports to have Teflon pad on top of slide
plate of spring. Load column of these spring supports shall be internally
guided.
Page 21 of 29
Reliance Industries Limited
RIL - OT KGD6
Pipe Stress Analysis & Pipe Supports Design Criteria
OTBC-B00-31070484-PPL-0001
11)
Accurate weight calculation shall be made to determine the supporting
force at each spring support location and the pipe weight loading at each
rotating equipment location.
12)
The weight calculation at all spring support locations shall include the
weight of pipe, fittings, valves and specialties, the weight of the medium
transported, weight of insulation used.
13)
The total travel for constant supports shall be equal to the actual travel plus
20%. In no case shall the difference between actual and total travel be less
than 1” (25 mm).
14)
Constant and variable springs shall be provided with travel stops:
15)
These stops shall be installed at the factory where the spring shall be preset to the specified installed load, and shall be strong enough to resist the
hydrostatic test loading on the unit. These stops shall be re-usable and
either stored in attached storage pouches or permanently attached to the
spring housing, when not in use.
16)
The travel range of each spring selected shall be checked to ensure that
any upset temperature or steam-out condition can be satisfied within the
limits of the working range of the spring.
17)
Where pipelines have been analyzed by the Pipe Stress Engineer and line
movements are available on the computer output sheets, these movements
shall be used for the spring computations.
18)
All the Variable Spring Supports (VSS) and Constant Spring Supports
(CSS) shall be properly numbered and area wise spring log shall be
maintained. Following philosophy shall be adopted for numbering the spring
hangers:
VSS – 01 – 001
Sequence numbers
Area Number
Type of Spring Support
VSS for Variable Spring Support and CSS for constant spring support
19)
20)
4.8
Separate sequence numbers shall be maintained for VSS and CSS.
Wherever the Base Type springs (CSH / VSH) are used on horizontal big
bore lines of dia. 20” and above, instead of single spring, double spring
should be used to avoid the rotation.
For all the pedestal type spring hangers provided for lines of Dia. 20” and
above separate sketch (with SPS nos. as well as Spring Tag nos.) shall be
prepared to indicate the installation details etc.
Sleepers and Grade Piers for Supports
1)
Sliding base supports with pipe loads, which do not exceed 10kN shall rest
directly on pedestals as specified in support standard.
2)
Where anchors and / or stops specified at sleepers or base piers, the
calculated reactions exceeding 10kN vertical or 5kN horizontal shall be
transmitted to the Civil Engineering Group. The Civil Engineering Group
Page 22 of 29
Reliance Industries Limited
RIL - OT KGD6
Pipe Stress Analysis & Pipe Supports Design Criteria
OTBC-B00-31070484-PPL-0001
shall design the appropriate foundations to sustain the reactions (NB. Not
applicable to Package Sellers).
Page 23 of 29
Pipe Stress Analysis & Pipe Supports Design Criteria
OTBC-B00-31070484-PPL-0001
Reliance Industries Limited
RIL - OT KGD6
PIPE SPANS
Assumptions and Notes
Material: The properties of Carbon Steel have been used.
Modulus of Elasticity (E) = 210 Gpa (210,000 N/mm^2)
Density = 7900 kg/m^3
Density of contents, for liquid filled case (for all cases where insulation reads 0, 40, 75, & 100mm) =
1000 kg/m^3
Density of insulation (where insulation reads 40, 75, & 100mm) = 177kg/m^3 (from MEC
documentation)
Three different methods for assessing the maximum permissible span length have been used:
1. Maximum span based on the maximum allowable bending stress at the mid-span of the beam.
Based on a simply supported beam.
Maximum allowable stress limited to 0.25 x Sh. For CS less than 200C, Sh = 137.9 Mpa.
Therefore S = 34.5 Mpa. Formula for length based on mid-span bending stress is:
L
2.
L
Where:
S = Allowable Stress, 34.5MPa
I = Second Moment of Area mm^4
w = Weight per unit length of pipe, N/mm
D = Outside diameter of pipe in mm.
L = Span length in mm.
Maximum span based on the deflection allowed at the mid-point of the span. Limited this to 10 mm
for less than 4" NB, and 8 mm for pipes 4" NB and above. For simply supported beam:
Deflection
3.
16 SI
wD
5
384
wL4
EI
Where:
w = Weight per unit length of pipe, N/mm
I = Second Moment of Area mm^4
L = Span length in mm.
E = Youngs modulus MPa.
Deflection = 8mm, or 10mm (see above).
Maximum span based on the indentation at the pipe support. Typically this comes into effect with
large bore thin walled pipe. The calculation tabulated based on bare pipe resting on beams 100mm
long. In this case the local stress is limited to 0.67Sh (or 92.4MPa for carbon steel pipe less than
200C).
In many cases a shoe will be used, and the onus is on the stress engineer to check spans as
required.
Local stress in shell under local loading gives:
S (d
b )t 2
0 . 644 w Rt
Page 24 of 29
Where:
w = Weight per unit length of pipe, N/mm
S = Allowable Stress, 92.4MPa.
L = Span length in mm
R = Radius of pipe mm
t = corroded thickness of pipe mm
Deflection = 8mm, or 10mm (see above)
d = bearing length = 100mm
b = bearing width mm, 16.5mm for
42"NB pipe and directly proportional for
other sizes
Pipe Stress Analysis & Pipe Supports Design Criteria
OTBC-B00-31070484-PPL-0001
Reliance Industries Limited
RIL - OT KGD6
NB - The following tabulated results have been rounded up to the nearest hundred.
SPAN CHART FOR 1” TO 10” (Up to 200 C Max)
Schd
No
10S
STD
40
XS
80
160
XXS
Insulation
Thickness
mm
EMPTY
0
40
75
100
EMPTY
0
40
75
100
EMPTY
0
40
75
100
EMPTY
0
40
75
100
EMPTY
0
40
75
100
EMPTY
0
40
75
100
EMPTY
0
40
75
100
1"
1.5"
2"
3"
4"
6"
8"
10"
Max Span
Length
mm
Max Span
Length
mm
4900
4400
4100
3600
3100
Max
Span
Length
mm
5500
4900
4500
4100
3600
4800
4500
4300
3900
3600
4800
4500
4300
3900
3600
4700
4500
4300
4000
3800
4500
4500
4300
4000
3900
5300
5100
4800
4500
4300
5300
5100
4800
4500
4300
5200
5100
4900
4600
4400
5100
5000
4800
4600
4500
Max
Span
Length
mm
6300
5400
5200
4900
4600
6200
5700
5500
5200
5000
6200
5700
5500
5200
5000
6200
5800
5600
5400
5200
6200
5800
5600
5400
5200
6000
5800
5700
5500
5300
5900
5800
5600
5500
5400
Max
Span
Length
mm
7200
6000
5700
5500
5300
7100
6400
6200
6000
5800
7100
6400
6200
6000
5800
7000
6500
6400
6200
6000
7000
6500
6400
6200
6000
6900
6600
6500
6300
6200
6800
6600
6500
6300
6200
Max
Span
Length
mm
8700
7000
6800
6500
6400
8600
7600
7400
7300
7100
8600
7600
7400
7300
7100
8500
7900
7700
7600
7400
8500
7900
7700
7600
7400
8400
8000
7900
7800
7700
8300
8000
7900
7800
7700
Max
Span
Length
mm
10000
7700
7600
7400
7200
9900
8600
8400
8300
8100
9900
8600
8400
8300
8100
9800
8900
8800
8600
8500
9800
8900
8800
8600
8500
9500
9100
9000
8900
8800
9500
9100
9000
8900
8800
Max
Span
Length
mm
11100
8440
8271
8106
7974
10975
9425
9284
9141
9032
10975
9425
9284
9141
9032
10907
9717
9591
9464
9365
10859
9846
9730
9611
9518
10598
10103
10021
9935
9868
10659
10083
9995
9904
9832
4000
3800
3400
2800
2300
3900
3800
3500
3000
2600
3900
3800
3500
3000
2600
3800
3700
3500
3200
2800
3700
3700
3400
3200
2800
Page 25 of 29
Pipe Stress Analysis & Pipe Supports Design Criteria
OTBC-B00-31070484-PPL-0001
Reliance Industries Limited
RIL - OT KGD6
SPAN CHART FOR 12” TO 20” (Up to 200C Max)
Schd No
10S
STD
40
XS
80
160
Insulation
Thickness
mm
12"
14"
16"
EMPTY
Max
Span
Length
mm
12100
Max
Span
Length
mm
12700
4.78
Max
Span
Length
mm
13600
4.78
Max
Span
Length
mm
14400
5.54
Max
Span
Length
mm
15200
0
9100
9000
4.78
9900
4.78
10100
5.54
10800
40
9000
8400
4.78
9700
4.78
9900
5.54
10600
75
8800
7900
4.78
9400
4.78
9600
5.54
10400
Pad
thick
mm
18"
Pad
thick
mm
20"
Pad
thick
mm
100
8600
7600
4.78
9200
4.78
9500
5.54
10200
EMPTY
12000
12600
9.53
13500
9.53
14300
9.53
15100
0
10100
10500
9.53
11000
9.53
11500
9.53
11900
40
10000
10400
9.53
10900
9.53
11400
9.53
11800
75
9900
10200
9.53
10800
9.53
11300
9.53
11700
100
9800
9900
9.53
10700
9.53
11200
9.53
11600
EMPTY
12000
12600
12.70
13500
14300
15100
0
10200
10700
12.70
11400
12100
11500
40
10100
10600
12.70
11300
12000
11100
75
10000
10500
12.70
11200
11900
10800
100
9900
10400
12.70
11100
11800
10500
EMPTY
12000
12600
13500
14300
15100
0
10500
10900
11400
11000
8900
40
10300
10700
11300
10600
8600
75
10200
10600
11200
10200
8300
100
10100
10500
11100
9900
8100
EMPTY
11900
12500
13300
14100
14900
0
10800
11300
12000
12700
13400
40
10600
11200
11900
12600
13300
75
10500
11100
11800
12600
13200
100
10500
11000
11800
12500
13200
EMPTY
11600
12200
13000
13800
14500
0
11100
11600
12400
13100
13800
40
11000
11500
12300
13000
13800
75
10900
11400
12200
13000
13700
100
10800
11400
12200
12900
13700
Page 26 of 29
Pipe Stress Analysis & Pipe Supports Design Criteria
OTBC-B00-31070484-PPL-0001
Reliance Industries Limited
RIL - OT KGD6
SPAN CHART FOR 24” TO 48” (10S to 20mm thick)
(Up to 200 C Max)
Schd No
10S
STD
40
XS
80
160
20
mm
Insulatio
n
Thicknes
s mm
EMPTY
0
40
75
100
EMPTY
0
40
75
100
EMPTY
0
40
75
100
EMPTY
0
40
75
100
EMPTY
0
40
75
100
EMPTY
0
40
75
100
EMPTY
0
40
75
100
24"
Pad
thick
mm
Max
Span
Length
mm
6.35
6.35
6.35
6.35
6.35
9.53
9.53
9.53
9.53
9.53
17.48
17.48
17.48
17.48
17.48
12.70
12.70
12.70
12.70
12.70
30.96
30.96
30.96
30.96
30.96
59.54
59.54
59.54
59.54
59.54
16100
11100
10700
10300
10000
16100
12300
12200
12100
12000
16000
13400
13300
13200
13200
16000
12800
12700
12700
12600
15800
14200
14100
14000
14000
15400
14600
14600
14500
14500
30"
Pad
thick
mm
Max
Span
Length
mm
7.92
7.92
7.92
7.92
7.92
9.53
9.53
9.53
9.53
9.53
18000
9100
8800
8600
8400
18000
8900
8600
8400
8200
36"
Pad
thick
mm
Max
Span
Length
mm
12.70
12.70
12.70
12.70
12.70
17900
13500
13100
12800
12600
19.05
19.05
19.05
19.05
19.05
12.70
12.70
12.70
12.70
12.70
20.00
20.00
20.00
20.00
20.00
17800
14800
14700
14700
14600
20.00
20.00
20.00
20.00
20.00
Page 27 of 29
42"
Pad
thick
mm
Max
Span
Length
mm
19600
15200
14900
14600
14400
19700
8800
8600
8400
8300
12.70
12.70
12.70
12.70
12.70
21300
6700
6500
6400
6300
19600
15800
15700
15600
15400
20.00
20.00
20.00
20.00
20.00
21200
12400
12100
11900
11800
48"
Pad
thick
mm
Max
Span
Length
mm
20.00
20.00
20.00
20.00
20.00
22700
9500
9300
9200
9100
Pipe Stress Analysis & Pipe Supports Design Criteria
OTBC-B00-31070484-PPL-0001
Reliance Industries Limited
RIL - OT KGD6
SPAN CHART FOR 24” TO 48” (25 mm to 70 mm thick)
(Up to 200 C Max)
Schd No
Insulation
Thickness
mm
24"
25
mm
30
mm
40
mm
50
mm
60
mm
70
mm
36"
42"
48"
Pad
thick
mm
Max
Span
Length
mm
Pad
thick
mm
Max
Span
Length
mm
Pad
thick
mm
Max
Span
Length
mm
Pad
thick
mm
Max
Span
Length
mm
EMPTY
25.00
17800
25.00
19500
25.00
21100
25.00
22600
0
25.00
15200
25.00
16300
25.00
16300
25.00
12600
40
25.00
15100
25.00
16200
25.00
16100
25.00
12400
75
25.00
15100
25.00
16200
25.00
15800
25.00
12200
100
25.00
15000
25.00
Pad
thick
mm
Max
Span
Length
mm
30"
16100
25.00
15700
25.00
12100
EMPTY
17700
16000
30.00
21100
30.00
22600
0
12700
8600
30.00
17700
30.00
15700
40
12400
8400
30.00
17600
30.00
15500
75
12200
8300
30.00
17500
30.00
15300
100
12100
8200
30.00
17500
30.00
15100
EMPTY
17600
19400
16300
13600
0
15900
12000
9400
7300
40
15800
11800
9200
7200
75
15800
11600
9100
7100
100
15700
11500
9000
7100
EMPTY
17500
19300
18900
15700
0
16100
15200
12000
9400
40
16100
15000
11800
9300
75
16000
14800
11700
9200
100
16000
14700
11600
9100
EMPTY
17400
19200
20800
17600
0
16300
17700
14500
11400
40
16200
17600
14300
11300
75
16200
17600
14200
11200
100
16100
17500
14000
11100
EMPTY
17300
19100
20700
19400
0
16300
17800
16900
13300
40
16300
17700
16700
13200
75
16200
17700
16500
13100
100
16200
17700
16400
13000
Page 28 of 29
Reliance Industries Limited
RIL - OT KGD6
Pipe Stress Analysis & Pipe Supports Design Criteria
OTBC-B00-31070484-PPL-0001
REDUCTION GUIDE FOR ALLOWABLE SPANS BASED ON CONFIGURATION.
Pipe spans listed previously have been based on straight pipe between supports. For cases A
through G below, multiply the allowable pipe span by the appropriate coefficient.
Page 29 of 29
Doc.No. : 2001-KGD6-D2-PF-ON-OTBC-B00-31070484-PPL-0001
Sht. 1 of 1
Annexure - A
SEISMIC FACTOR CALCULATION
The horizontal seismic co-efficient is calculated by response spectrum method,
as per IS 1893-2002.
Seismic Zone III
The horizontal seismic co-efficient is calculated as follows:
Z  I
Ah area     
 2   R area
  Sa
  
  g
I
Z 
Ah Piperack     

 2   R piperack

  0 .1684  0 .169

  Sa 

  0 .0963
  g 

Vertical Seismic coefficient for Area Design = 2/3 x Ah Area = 0.113
Vertical Seismic coefficient for piperack Design = 2/3 x Ah Piperack = 0.0642
Steel strcture seismic parameter is considered for the Area.
RCC structure seimic parameter is considered for the Piperack
Where;
Ah
= Horizontal seismic coefficient
Z
= Seismic zone factor = 0.22
I
= 1.75
RArea = 4
RPiperack
=5
Sa
/g Area = 2.5 with 2% damping factor = 3.5
Sa
/g Piperack = 2.5 with 5% damping factor = 2.5
(Damping factor as per table 3)
(Damping factor as per table 3)
" g " Factor For Area Piping Design
Caeser II input to use "g" option for uniform load ( in X & Z direction ) ,
= 0.169
Caeser II input to use "g" option for uniform load ( in Y direction ) ,
= 0.113
" g " Factor For Concrete Piperack Piping ( Area 01 , 02 , 04 )
Caeser II input to use "g" option for uniform load ( in X & Z direction ) , = 0.0963
Caeser II input to use "g" option for uniform load ( in Y direction ) ,
= 0.0642
Referenced doc. 2001-KGD6-D2-PF-ON-OTBC-B00-31070484-CIL-0701
OTBC-B00-31070488-PPL-0001-Attach B
OTBC-B00-31-7070484-PPL-001
Doc. No. : 2001-KGD6-D2-PF-ON-OTBC-B00-31070484-PPL-0001
Annexure B
( Caesar II
Configuration set up )
Ver. 5.300
EGAMEMORY =
128K
10
CONNECT_GEOMETRY_THRU_CNODES =
YES
34
1.
MIN_ALLOWED_BEND_ANGLE =
0.5000000E+01
36
MAX_ALLOWED_BEND_ANGLE =
0.9500000E+02
37
BEND_LENGTH_ATTACHMENT_PERCENT =
0.1000000E+01
38
MIN_ANGLE_TO_ADJACENT_BEND_PT =
0.5000000E+01
39
LOOP_CLOSURE_TOLERANCE =
0.1000000E+01
42
THERMAL_BOWING_HORZ_TOLERANCE =
0.1000000E-03
92
AUTO_NODE_NUMBER_INCREMENT=
0.1000000E+02 109
Z_AXIS_UP=
NO
129
0.
USE_PRESSURE_STIFFENING =
DEFAULT
65
2.
ALPHA_TOLERANCE =
0.5000000E-01
33
RESLD-FORCE =
NO
44
0.
HGR_DEF_RESWGT_STIF =
0.1000000E+13
49
DECOMP_SNG_TOL =
0.1000000E+11
50
BEND_AXIAL_SHAPE =
YES
51
1.
FRICT_STIF =
0.1000000E+07
45
FRICT_NORM_FORCE_VAR =
0.1500000E+00
47
FRICT_ANGLE_VAR =
0.1500000E+02
48
FRICT_SLIDE_MULT =
0.1000000E+01
46
ROD_TOLERANCE =
0.1000000E+01
59
ROD_INC =
0.2000000E+01
58
INCORE_NUMERICAL_CHECK =
NO
60
0.
OUTCORE_NUMERICAL_CHECK =
NO
61
0.
DEFAULT_TRANS_RESTRAINT_STIFF=
0.1000000E+13
98
DEFAULT_ROT_RESTRAINT_STIFF=
0.1000000E+13
99
IGNORE_SPRING_HANGER_STIFFNESS =
NO
100
0.
MISSING_MASS_ZPA =
EXTRACTED
101
1.
MIN_WALL_MILL_TOLERANCE =
0.1250000E+02 107
WRC-107_VERSION =
MAR_79_1B1/2B1
119
3.
WRC-107_INTERPOLATION =
LAST_VALUE
120
1.
DEFAULT_AMBIENT_TEMPERATURE=
0.7000000E+02 135 = 16.6 C
BOURDON_PRESSURE=
NONE
136
0.
COEFFICIENT_OF_FRICTION_(MU) =
0.3000000E+00 140
INCLUDE_SPRG_STIF_IN_HGR_OPE =
NO
141
0.
INCLUDE_INSULATION_IN_HYDROTEST = YES
147
1.
REDUCED_INTERSECTION =
B31.1(POST1980)
32
1.
USE_WRC329
NO
62
0.
NO_REDUCED_SIF_FOR_RFT_AND_WLT
NO
53
0.
B31.1_REDUCED_Z_FIX =
YES
54
1.
CLASS_1_BRANCH_FLEX
NO
55
0.
ALL_STRESS_CASES_CORRODED =
NO
35
0.
ADD_TORSION_IN_SL_STRESS =
DEFAULT
66
2.
ADD_F/A_IN_STRESS =
YES
67
0.
OCCASIONAL_LOAD_FACTOR =
0.0000000E+00
41
DEFAULT_CODE =
B31.3
43
3.
B31.3_SUS_CASE_SIF_FACTOR =
0.7500000E+00
40
ALLOW_USERS_BEND_SIF =
NO
52
0.
OTBC-B00-31-7070484-PPL-001
Doc. No. : 2001-KGD6-D2-PF-ON-OTBC-B00-31070484-PPL-0001
Annexure B
( Caesar II
Configuration set up )
USE_SCHNEIDER
YIELD_CRITERION_STRESS =
USE_PD/4T
BASE_HOOP_STRESS_ON_? =
NO
MAX_3D_SHEAR
NO
ID
Page 1
63
108
64
57
0.
0.
0.
0.
OTBC-B00-31070488-PPL-0001-Attach B
EN13480_USE_IN_OUTPLANE_SIFS=
NO
133
LIBERAL_EXPANSION_ALLOWABLE=
YES
137
B31.3_SEC_319.2.3C_SAXIAL=
(|Sa|+Sb)^2
146
B31.3_WELDING/CONTOUR_TEE_ISB16.9 FALSE
139
PRESSURE_VARIATION_IN_EXP_CASE=
DEFAULT
143
IMPLEMENT_B313_APP-P
NO
144
IMPLEMENT_B313_CODE_CASE_178
NO
145
IGNORE_B31.1/B31.3_Wc_FACTOR=
NO
148
USE_FRP_SIF =
YES
110
USE_FRP_FLEX =
YES
111
BS_7159_Pressure_Stiffening=
Design_Strain
121
FRP_Property_Data_File=
CAESAR.FRP
122
FRP_Emod_(axial) =
0.3200000E+07 113
FRP_Ratio_Gmod/Emod_(axial) =
0.2500000E+00 114
FRP_Ea/Eh*Vh/a =
0.1527300E+00 115
FRP_Laminate_Type =
THREE
116
FRP_Alpha =
0.1200000E+02 117
FRP_Density =
0.6000000E-01 118
EXCLUDE_f2_FROM_UKOOA_BENDING =
NO
134
INTRO_EXIT_SCREENS
ON
85
YES/NO/ARE_YOU_SURE_PROMPTS
ON
86
OUTPUT_REPORTS_BY_LOAD_CASE
YES
87
DISPLACEMENT_NODAL_SORTING
YES
89
DYNAMIC_INPUT_EXAMPLE_TEXT
MAX
94
TIME_HIST_ANIMATE
YES
104
OUTPUT_TABLE_OF_CONTENTS
ON
105
INPUT_FUNCTION_KEYS_DISPLAYED
YES
106
ENABLE_AUTOSAVE
YES
130
AUTOSAVE_TIME_INTERVAL
0.3000000E+02 131
PROMPTED_AUTOSAVE
YES
132
DISABLE_UNDO/REDO
NO
128
STRCT_DBASE=
AISC89.BIN
70
VALVE_&_FLANGE=
CADWORX.VHD
90
EXPANSION_JT_DBASE=
FLEXPATH.JHD
91
PIPING_SIZE_SPECIFICATION
DIN
88
DEFAULT_SPRING_HANGER_TABLE=
0.5000000E+01 112
SYSTEM_DIRECTORY_NAME=
SYSTEM
123
UNITS_FILE_NAME=
KGD6.FIL
124
ENABLE_ODBC_OUTPUT=
NO
125
APPEND_RERUNS=
NO
126
LOADCASE_TEMPLATE=
LOAD.TPL
142
Valve/Flange_Dbase_File_Location= CAESARII_DIR
149
User_Material_File_Name=
UMAT1.UMD
150
ODBC_DATABASE_NAME=
<none>
127
0.
1.
2.
0.
2.
0.
0.
0.
1.
1.
1.
1.
3.
0.
1.
1.
1.
1.
0.
1.
1.
1.
1.
1.
0.
1.
1.
1.
3.
1.
0.
0.
0.
1.
1.
1.
0.
OTBC-B00-31-7070484-PPL-001
Doc. No. : 2001-KGD6-D2-PF-ON-OTBC-B00-31070484-PPL-0001
Annexure B
( Caesar II
Configuration set up )
INPUT UNITS USED...
UNITS= SI (mm) NOM/SCH INPUT= ON
LENGTH
inches
FORCE
pounds
MASS(dynamics)
pounds
MOMENTS(INPUT)
inch-pounds
MOMENTS(OUTPUT)
inch-pounds
STRESS
lbs./sq.in.
TEMP. SCALE
degrees F.
PRESSURE
psig
ELASTIC MODULUS
lbs./sq.in.
PIPE DENSITY
lbs./cu.in.
x
25.400
x
4.448
x
0.454
x
0.113
x
0.113
x
6.895
x
0.556
x
0.069
x
6.895
x 27680.000
Page 2
=
=
=
=
=
=
=
=
=
=
mm.
N.
kg.
N.m.
N.m.
KPa
C
bars
KPa
kg/cu.m.
INSULATION DENS.
FLUID DENSITY
TRANSL. STIF
ROTATIONAL STIF
UNIFORM LOAD
G LOAD
WIND LOAD
ELEVATION
COMPOUND LENGTH
DIAMETER
WALL THICKNESS
OTBC-B00-31070488-PPL-0001-Attach
lbs./cu.in.
x 27680.000
=
lbs./cu.in.
x 27680.000
=
lbs./in.
x
1.751
=
in.lb./deg.
x
0.113
=
lb./in.
x
0.175
=
g's
x
1.000
=
lbs./sq.in.
x
6.895
=
inches
x
0.025
=
inches
x
25.400
=
inches
x
25.400
=
inches
x
25.400
=
Page 3
B
kg/cu.m.
kg/cu.m.
N./cm.
N.m./deg
N./mm.
g's
KPa
m.
mm.
mm.
mm.
Sht. 1 of 1
Doc. No.: 2001-KGD6-D2-PF-ON-OTBC-B00-31070484-PPL-0001
ANNEXURE :- D
NOZZLE LOADING COMPARISON SHEET
CALCULATION NO.
EQUIPMENT / NOZZLE NO.
Nozzle
Nozzle
Dia,
Rating.
Node No.:Forces (N)
Fa
Fl
Moments (N-m)
Fc
Mc
Ml
Mt
Allowable Loading
Calculated Loading For
Design condition (Max)
Design condition (Min)
Operating condition
EQUIPMENT / NOZZLE NO.
Nozzle
Nozzle
Dia,
Rating.
Node No.:Forces (N)
Fa
Fl
Moments (N-m)
Fc
Mc
Ml
Mt
Allowable Loading
Calculated Loading For
Design condition (Max)
Design condition (Min)
Operating condition
EQUIPMENT / NOZZLE NO.
Nozzle
Nozzle
Dia,
Rating.
Allowable Loading
Calculated Loading For
Design condition (Max)
Design condition (Min)
Operating condition
Notes :
Node No.:Forces (N)
Fa
Fl
Moments (N-m)
Fc
Mc
Ml
Mt
Sht. 1 of 1
Doc. No. : 2001-KGD6-D2-PF-ON-OTBC-B00-31070484-PPL-0001
Annexure - F
NOZZLE LOADS FOR PRESSURE VESSEL, SHELL & TUBE HEAT EXCHANGERS AT THE FACE OF FLANGE
TABLE 1:SIZE
(150#)
DN
FA=FL
inches
FC
(300#)
MC=ML
MT
FA=FL
FC
(600#)
MC=ML
MT
FA=FL
FC
(900#)
MC=ML
MT
FA=FL
FC
(1500#)
MC=ML
MT
FA=FL
FC
(2500#)
MC=ML
MT
FA=FL
FC
SIZE
MC=ML
MT
inches
2
50
3000
2250
390
450
4000
3000
520
600
5000
3750
650
750
6000
4500
780
900
8000
6000
1040
1200
11200
8400
1456
1680
2
3
80
4500
3375
878
1013
6000
4500
1170
1350
7500
5625
1463
1688
9000
6750
1755
2025
12000
9000
2340
2700
16800
12600
3276
3780
3
4
100
6000
4500
1560
1800
8000
6000
2080
2400
10000
7500
2600
3000
12000
9000
3120
3600
16000
12000
4160
4800
22400
16800
5824
6720
4
6
150
9000
6750
3510
4050
12000
9000
4680
5400
15000
11250
5850
6750
18000
13500
7020
8100
24000
18000
9360
10800
33600
25200
13104
15120
6
8
200
12000
9000
6240
7200
16000
12000
8320
9600
20000
15000
10400
12000
24000
18000
12480
14400
32000
24000
16640
19200
44800
33600
23296
26880
8
10
250
15000
11250
9750
11250
20000
15000
13000
15000
25000
18750
16250
18750
30000
22500
19500
22500
40000
30000
26000
30000
56000
42000
36400
42000
10
12
300
18000
13500
14040
16200
24000
18000
18720
21600
30000
22500
23400
27000
36000
27000
28080
32400
48000
36000
37440
43200
67200
50400
52416
60480
12
14
350
21000
15750
19110
22050
28000
21000
25480
29400
35000
26250
31850
36750
42000
31500
38220
44100
56000
42000
50960
58800
78400
58800
71344
82320
14
16
400
24000
18000
24960
28800
32000
24000
33280
38400
40000
30000
41600
48000
48000
36000
49920
57600
64000
48000
66560
76800
89600
67200
93184
107520
16
18
450
27000
20250
31590
36450
36000
27000
42120
48600
45000
33750
52650
60750
54000
40500
63180
72900
72000
54000
84240
97200
100800
75600
117936
136080
18
20
500
30000
22500
39000
45000
40000
30000
52000
60000
50000
37500
65000
75000
60000
45000
78000
90000
80000
60000
104000
120000
112000
84000
145600
168000
20
22
550
33000
24750
47190
54450
44000
33000
62920
72600
55000
41250
78650
90750
66000
49500
94380
108900
88000
66000
125840
145200
123200
92400
176176
203280
22
24
600
36000
27000
56160
64800
48000
36000
74880
86400
60000
45000
93600
108000
72000
54000
112320
129600
96000
72000
149760
172800
134400
100800
209664
241920
24
26
650
39000
29250
65910
76050
52000
39000
87880
101400
65000
48750
109850
126750
78000
58500
131820
152100
104000
78000
175760
202800
145600
109200
246064
283920
26
28
700
42000
31500
76440
88200
56000
42000
101920
117600
70000
52500
127400
147000
84000
63000
152880
176400
112000
84000
203840
235200
156800
117600
285376
329280
28
30
750
45000
33750
87750
101250
60000
45000
117000
135000
75000
56250
146250
168750
90000
67500
175500
202500
120000
90000
234000
270000
168000
126000
327600
378000
30
32
800
48000
36000
99840
115200
64000
48000
133120
153600
80000
60000
166400
192000
96000
72000
199680
230400
128000
96000
266240
307200
179200
134400
372736
430080
32
34
850
51000
38250
112710
130050
68000
51000
150280
173400
85000
63750
187850
216750
102000
76500
225420
260100
136000
102000
300560
346800
190400
142800
420784
485520
34
36
900
54000
40500
126360
145800
72000
54000
168480
194400
90000
67500
210600
243000
108000
81000
252720
291600
144000
108000
336960
388800
201600
151200
471744
544320
36
38
950
57000
42750
140790
162450
76000
57000
187720
216600
95000
71250
234650
270750
114000
85500
281580
324900
152000
114000
375440
433200
212800
159600
525616
606480
38
40
1000
60000
45000
156000
180000
80000
60000
208000
240000
100000
75000
260000
300000
120000
90000
312000
360000
160000
120000
416000
480000
224000
168000
582400
672000
40