3. 5. 9. PURCHASER Contract- Mar 21, 2011 Page 41 of 108

Based on the current workload, the following software deliverables schedule shall apply.
Any delay of the FNTP beyond 8 weeks past the LNTP date, will result in corresponding delays in the drawing delivery schedule.
Delivery Date Remarks Item Description (Weeks After
Receipt of LOI/ FNTP), as
defined under Remarks
2. Preliminary HRSG Foundation Footprint, 8 Completed Details & Foundation Load Chart
3. Preliminary HRSG General Arrangement 8 Completed Drawings - Plan & Elevation
4. HRSG P&ID Drawings HP, IP & LP 4 Completed Systems (First Release)
5. Module Weights and Dimensions 14 Completed Module Head & Tail Lifting Lug Details 6 Completed and Location
6. Trim List (Valves & Instrumentation) 10 Completed
7. N/E Shipping Sequence List (finals prior to 16 Completed shipment)
8. Final HRSG Foundation Footprint, Details 10 Completed & Foundation Load Chart
9. HRSG General Arrangement Drawings- 10 Completed Plan & Elevation (Unit Layout Drawings)
10. General Arrangement - Platform, Stairs & 12 Completed Ladders
11. Large Bore Piping Terminal Points 14 Completed Interface Details
12. Duct Burner P&ID's 12 FNTP
PURCHASER Contract- Mar 21, 2011 Page 41 of 108 Execution Document
13. Field Erection Manual 12 FNTP
14. Control LoQic DiaQrams 20 FNTP 15. Erection Drawings 30 FNTP
16. HRSG Operation & Maintenance Manuals a. NIE Manual text write-up 32 FNTP b. NIE subvendor information 52 FNTP
17. ASME Code Data Package 60 days after field hydrotest reports
18. HRSG Startup Curves Based on GSPC 4 - preliminary Completed Steam Turbine Startup Curves May need to be
updated if GT data is updated
19. HP, IP & LP Feedwater Control Valve 4 (Pressure drop Completed Pressure Droo And Characteristics at max. flow)
20. HP, IP & LP Feedwater Flow 4- Preliminary • Completed Measurement Device Pressure Droo 12 ·Final
21. HP, IP & LP Steam Flow Measurement 3- Preliminary Completed Device Pressure Drop . after provided
detailed piping information
22 Casing I Ducting Detailed Fabrications 12 Completed Drawings I Field Erection Only
23 Small Bore Piping 4 Comoleted 24 Steam Blow Conditions 4 Completed 25 Module Detailed Fabrication Drawings I 10 FNTP
Field Erection Onlv 26 Blowdown Tank Svstem 12 FNTP 27 HPIIPILP Drum Detailed Design Drawings 4 FNTP
a. Two week turn around time for Purchaser comments required for reviewing drawings.
b. NIE will supply electronic drawing files in a ".tif' format.
PURCHASER Contract-Mar 21, 2011 Page 42 ofl 08 Execution Document
GENTLEMEN:
-DRAFT-
8TH AND LOCUST STREETS ST. LOUIS, MO 63101
-----''' 2009
BY ORDER OF OUR CLIENT, NOOTERIERIKSEN, INC., A MISSOURI CORPORATION, 1509 OCELLO DRIVE, FENTON, MISSOURI 63026, TOGETHER WITH ITS SUCCESSORS AND ASSIGNS ("SELLER"), SELLER'S BANK HEREBY OPENS IRREVOCABLE LETTER OF CREDIT, NO. (THE "LETTER OF CREDIT"), IN THE FAVOR OF , TOGETHER WITH THEIR SUCCESSORS AND ASSIGNS ("BUYER"), FOR THE AMOUNT OF
UNITED STATES DOLLARS (US$ ). THIS LETTER OF '""c-=R-=E ..... D'""IT:-("'1)--,S,..,H"'"'A:-:-L-:-L BECOME EFFECTIVE IMMEDIATELY AND SHALL EXPIRE NO LATER THAN , AT OUR COUNTERS IN ST. LOUIS, MISSOURI, U.S.A., AND (II) IS SUBJECT TO THE FOLLOWING:
1. FUNDS UNDER THIS LETTER OF CREDIT ARE AVAILABLE TO YOU UPON PRESENTATION OF YOUR DRAFT(S) DRAWN BY BUYER ON SELLER'S BANK AT SIGHT, SETTING FORTH THEREON SELLER'S BANK LETTER OF CREDIT NO._ ..,...,...,="'"'' TOGETHER WITH A STATEMENT PURPORTEDLY SIGNED BY AN AUTHORIZED OFFICIAL OF BUYER CERTIFYING:
"PURSUANT TO THE TERMS OF THE PURCHASE CONTRACT FOR THE AS OF . SELLER HAS
::-I N";::;C:-:-U:-::Rc=Rc=E=D-=T::-:Hc=E-::0:-:B::-L";::;I G:-:A-::T=:ION TO PAY (NOT TO EXCEED AMOUNT SET FORTH ABOVE)."
AND
"PURCHASER HAS IN WRITING NOTIFIED SELLER AT LEAST THIRTY (30) DAYS IN ADVANCE OF PURCHASER'S INTENTION TO DRAW ON THIS LETTER CREDIT NO. AS INDICATED BY THE LETTER
PURCHASER Contract -·Mar 21, 2011 Page 43 ofl 08 Execution Document
ATTACHED TO BUYER'S DOCUMENT PRESENTED TO DRAW UPON THIS LETTER OF CREDIT."
2. SELLER'S BANK HEREBY AGREES TO REDUCE OR TERMINATE THIS LETTER OF CREDIT ONLY UPON RECEIPT OF WRITTEN INSTRUCTION FROM BUYER. IN THE EVENT BUYER ELECT TO TERMINATE, THE ORIGINAL LETTER OF CREDIT MUST ACCOMPANY SUCH NOTICE.
3. SELLER'S BANK HEREBY AGREES WITH BUYER THAT BUYER'S DRAWING UNDER THIS LETTER OF CREDIT SHALL MEET WITH DUE HONOR, NO LATER THAN THREE BUSINESS DAYS, TO THE BANK ACCOUNT SPECIFIED BY BUYER IN ITS SIGHT DRAFT SUBMITTED HEREUNDER, IF RECEIVED BY SELLER'S BANK WITHIN THE TERM OF THIS LETTER OF CREDIT AND IF SUCH DRAWING COMPLIES WITH THE TERMS HEREOF. PARTIAL DRAWS UNDER THIS LETTER OF CREDIT SHALL BE PERMITTED.
4. THIS LETTER OF CREDIT IS SUBJECT TO THE INTERNATIONAL STANDBY PRACTICES ("ISP") OF THE INTERNATIONAL CHAMBER OF COMMERCE UNIFORM CUSTOMS AND PRACTICE FOR DOCUMENTARY CREDIT (LATEST REVISION) INTERNATIONAL CHAMBER OF COMMERCE PUBLICATION NO. 600. AS TO MATTERS NOT ADDRESSED BY THE ISP, THIS LETTER OF CREDIT SHALL BE GOVERNED BY AND CONSTRUED IN ACCORDANCE WITH THE LAWS OF THE STATE OF MISSOURI AND APPLICABLE U.S. FEDERAL LAW.
KINDLY ADDRESS ALL COMMUNICATIONS CONCERNING THIS LETTER OF CREDIT TO THE ATTENTION OF OUR LETTER OF CREDIT DEPARTMENT AT THE ABOVE ADDRESS, MENTIONING SPECIFICALLY OUR LETTER OF CREDIT NO.
SINCERELY,
U.S. BANK, N.A. INTERNATIONAL DEPT. SL-MO-L21L 8TH AND LOCUST STREETS\ ST. LOUIS, MO 63101
PURCHASER Contract- Mar 21, 2011 Page 44 of I 08 Execution Document
EXHIBIT 1- PERFORMANCE TEST PROCEDURE
1.0 INTRODUCTION
1.1 This document describes the basic performance test procedure which will be used by
Nooter!Eriksen to evaluate performance of a Heat Recovery Steam Generator (HRSG)
taking exhaust from a combustion gas turbine.
1.2 The primary objective of the performance tests will be to verify that the purchased
equipment has met all thermal performance guarantees per the commercial contracts.
Additional tests may also be performed to verify operational capabilities and to
characterize unit performance. These tests do not address guarantee verifications for
sound or emissions.
1.3 This test plan describes the general test approach, test instrumentation, test procedure,
equations to be used for calculating test results, and methods which will be used to
compare the HRSG (boiler) thermal performance to the guarantees.
1.4 Specific test procedures to be used in conducting the tests of each unit will be developed
at least 3 months prior to the test and submitted to the supplier for agreement and
approval. Deviations from the test procedure during the test period or during post-test
data analyses are acceptable if mutually agreed upon between all parties involved.
1.5 Where discrepancies exist between this generic test procedure, the specific unit test
procedures, and other published procedures or test codes, the specific unit test procedure
shall take precedence. Each procedure generally follows guidelines provided in ASME
Performance Test Code PTC 4.4-2008 (Gas Turbine Heat Recovery Steam Generators),
the latest editions of the PTC 19 series of codes on uncertainty and instrumentation, and
PTC 22-2005 (Gas Turbine Power Plants).
PURCHASER Contract-Mar 21, 20!1 Page 46 ofl 08 Execution Document
2.0 TEST RESPONSIBILITIES
The responsibilities for involved parties to the test are as follows:
2.1 Purchaser
• • •
• • •
• • • • •
•
Assist with power hook-up forNooter/Eriksen supplied test equipment . Assist with installation oftest instrumentation as needed . Provide scaffolding for the installation of inlet thermocouple grid . Provide sample containers, obtain samples and provide lab analysis of water . Inspect flow meters prior to the test. Program plant computer to provide required data. Dead bands shall be removed :from all recorded data points. Control the unit to the required operating conditions . Align system flows as required for the tests . Isolate leaking valves identified by the test team . Provide fuel sample cylinders and obtain fuel samples and analysis . Coordinate, perform and direct the test Assist with data collection .
2.2 Supplier
•
• • •
• •
-~
Provide test instrumentation and data acquisition system for instruments within Nooter/Eriksen scope of supply. Calibrate test instrumentation supplied by Nooter/Eriksen . Install test instrumentation supplied by Nooter/Eriksen . Perform a cycle isolation walkdown to identify leaking valves which may affect test results. Assist lead test team . Provide a computer model which will recalculate guaranteed performance at test conditions. Analyze test results and prepare test report.
PURCHASE~ Contract -'Mar 21; 201'1 Page 47 ·of 108 Execution Document
3.0 TYPICAL TEST PROCESS
3. I Prerequisites
The following actions should be completed by the appropriate party before initiation of the test:
a) The fuel flow orifice plates/flow meters to the gas turbine and duct burner shall be inspected prior to installation to assure proper condition. Proper installation and orientation shall be verified.
b) Feedwater and steam flow elements shall also be inspected to assure proper condition. Proper installation and orientation shall be verified.
c) Install necessary test instrumentation.
d) Record serial numbers and nameplate data of appropriate equipment being tested and equipment being used for the test.
e) Assign test personnel responsibilities and review procedures.
f) VerifY that a representative from each party is present (ifreqt~ired). The supplier shall be given at least two months ( 60 days) notice of the date on which HRSG performance tests are scheduled to be initiated.
g) The HRSG manufacturer and plant personnel should certifY that the HRSG is clean and that conditions are acceptable for testing.
h) Start unit under normal start-up procedures if not already running.
i) After start-up, check instruments and verifY data acquisition system operation.
j) Double block all manifolded vent and drain lines to eliminate bypassing of heat transfer surface.
k) Prior to starting the test, the combustion turbine and HRSG will be allowed to wann up to and stabilize at operating temperatures.
I) Perform a cycle isolation walkdown to verifY that the cycle is isolated. A checklist of isolation valves, drain valves, etc. will be used for the verification. The configuration of
PURCHASER Contract -Mar 21, 201I Page 48 of 108 Execution Document
these valves will be in accordance with the supplier's P&ID. A cycle isolation list is to
be provided at a later date.
m) For fired test cases, set the duct burner fuel flow to the desired heat input (based on
LHV). The heating value of the fuel used will be based on a preliminary fuel sample
analysis. Final performance evaluations will be based on analyses of samples taken
during the tests.
n) Verify that the feedwater flow is steady. Operate the flow control valve in automatic
mode unless the drum level is very unstable(± 1 %) in which case manual mode may be
required.
o) Verify the steam purity is steady. Steady conditions will be defined as at least two
consecutive sodium readings being practically the same.
p) Verify that the plant computer system is logging data at 1-minute intervals or less.
q) Verify duct burner status.
r) Verify power augmentation steam status.
s) Verify that the HR.SG and associated equipment is in normal operating condition for the
test.
t) Verify that test conditions are within acceptable tolerance of design conditions. Obtain
concurrence from each party representative.
3.2 Test
A) START DATA ACQUISITION FOR A ONE--HOUR DURATION AT THE TIME DESIGNATED BY THE TEST DIRECTOR. UNIT OPERATION SHOULD BE HELD CONSTANT. NO EQUIPMENT ADJUSTMENTS SHOULD BE MADE DURING THE TEST. THE PLANT COMPUTER DATA LOGGER SHOULD BE STARTED APPROXIMATELY TWO HOURS BEFORE A TEST AND SHOULD RUN FOR ONE HOUR AFTER THE COMPLETION OF A TEST OR UNTIL CONTROL OF THE UNIT IS VARIED. TillS DATA WILL BE USED TO CONFIRM STABLE OPERATION.
B) RECORD DATA ON THE MANUAL DATA SHEETS ONCE EVERY 5 MINUTES FOR THE DURATION OF THE TEST.
C) TIIENOOTERIERIKSENDATAACQUISITIONSYSTEMSHOULDRECORDDATAAT 30-SECOND INTERVALS FOR 1HE DURATION OF 1HE TEST.
d) The plant computer should be recording appropriate data at 1-minute intervals or less.
e) Obtain one fuel sample at the start of each test Fuel properties should be monitored for
consistency during the test If the on-line gas chromatograph shows a change in fuel
properties during the test, an additional fuel sample shall be taken at the middle and end
ofthe test.
f) Obtain one feed water sample and one steam sample every 5 minutes during the test If
available, online sampling of the sodium concentration should be monitored and recorded
on a continuous basis.
g) Record significant events, inconsistencies or adjustments made during the test.
h) Once the test is completed, all data takers should average the numbers on their data sheets
and return the completed sheet to the test director. Any discrepancies or questionable
items should be noted at that time. All parties to the test will sign the data sheets at the
completion of the test series. The vendor will receive copies of all data sheets at the
completion of each test run, if requested.
i) Preliminary perfonnance calculations shall be made based on the test results and
estimated fuel analysis. Final results will be calculated by entering all data into the
supplier's computer program and detennine the guaranteed output at the test conditions.
The results of this on-site analysis will be considered preliminary only. The supplier
shall have 30 days to recalculate fmal results after receipt of the final test data with actual
fuel analysis from the plant.
j) Proceed to the next test or unit operating condition. A minimum of two tests for each
operating case will be required (results averaged) to verifY perfonnance and repeatability.
PURCHASER Contract -'Mar 21, 2011 Page 50 of 108 Execution Document
4.0 ACCEPTANCE CRITERIA
4.1 Maximum permissible variations in test conditions as indicated in Table 3-5.3-1 of
ASME PTC 4.4-2008 are as follows:
Variable
Supplemental Fuel Flow
Feedwater Temperature to Economizer
Steam Temperature Leaving Superheater
±2%
± 1/2% of steam flow
±sop
±sop
±sop
±1%
4.2 Tests will be conducted at each guaranteed operating condition. At least two test runs
will be conducted for each guaranteed case in order to demonstrate repeatability of the
test runs.
4.3 The corrected steam parameters from two test runs at the same operating condition must
agree within the random uncertainty of the corrected results. If the two tests agree within
the random uncertainty of the corrected results, the results will be averaged to determine
unit performance for guarantee verification. If the two test runs do not agree, the cause of
the discrepancy should be investigated and eliminated, if possible. A third test should
then be performed and the results of any invalid test discarded. If the cause of the
discrepancy cannot be identified, the results of all tests will be discussed.
PURCHASER Contract- Mar 21·, 2011 Page 51-of 108 · Execution Document
5.0 TESTINSTRUMENTATION
All instruments will be calibrated prior to the test against standards traceable to the National
Institute of Standards and Technology (NIST). Test instrumentation calibration records will be
kept and made available to the owner to review and approve should test results be disputed.
A brief description of the typical types of test equipment used by Nooter/Eriksen is as follows.
Actual test instrumentation to be used during the test and the responsible party for the supply of
this equipment will be defmed in the specific unit test procedure.
5.1 Data Acquisition System
The Nooter/Eriksen performance test system utilizes distributed data acquisition junction
boxes. Each junction box contains an input module that converts analog inputs to digital
signals. Current inputs from pressure transmitters and watt meters enter ~achjunction box and pass through 0.01% precision resistors where the input module measures voltage
to determine the current signal generated by the instruments. Temperature inputs from RID's and thermocouples are similarly wired to junction boxes with inputs passing
through a thermistor reference directly into the measurement modules and then to the
data acquisition computer. Similar modules are also used for other instrumentation
inputs such as flow, rpm, direct voltage, etc.
Input module current readings are accurate to ± 0.03%. Each module is calibrated once
each year against standards traceable to NIST.
5.2 Temperature Measurements
Temperatures will be measured with 4-wire 100 ohm platinum RIDs or K-type
thermocouples. Temperature sensors are calibrated in a solid state dry block calibrator. All temperature sensors are calibrated against a Hart Scientific 5626 platinum standard
RTD, or equivalent. This standard is calibrated once each year by the supplier against a
standard traceable to NIST. Overall measW"ement accuracy including the element,
extension wire, reference junction, and DAS should be less than 0.5°C for temperatures
less than 300°C, and 1 oc for temperatures greater than 300°C.
5.3 Barometric Pressure
Barometric Pressure will be measured using an electronic absolute pressure cell, which
has an accuracy of±0.1% of reading (approx. 0.03 inches Hg) and is calibrated against a
standard traceable to NIST.
All static and differential pressures will be measured with Rosemount transmitters. The
transmitters will be calibrated against one of the following calibration standards as
appropriate for the application:
• Pneumatic dead weigh tester (accuracy of0.05% of reading)
This equipment is routinely calibrated by the supplier against standards traceable to
NIST.
should be less than 0.4%.
5.5 Air Relative Humiditv Measurement
A psychrometer will be used to measure the wet bulb temperature of the ambient air. The
psychrometer will consist of an RTD in a cotton wick, continuously wetted by a water
reservoir and aspirated by an induced draft electric fan. Specific and relative humidity
will be calculated from the wet bulb temperature, dry bulb temperatures, and barometric
pressure.
5.6 Sodiuin Concentration
If required, sodium concentration will be measured. Sodium concentration will be
measured by plant instrumentation as well as grab samples taken periodically throughout
the test. The samples should be examined by a qualified water chemistry lab with the
ability of measuring the sodium concentration within± 0.5%.
PURCHASER Contract-Mar 21, 2011 Page 53 of 108 Execution Document
6.0 TEST MEASUREMENTS
Specific listings of parameters to be measured, parameters to be calculated, test measurement points, and Nooter/Eriksen instrumentation to be used during testing will be provided in the specific test procedures developed for each unit tested. Typical installation guidelines and applications of the test instruments are as follows.
6. I Combustion Turbine Inlet Air Temperature
In obtaining the dry bulb temperatore, the square inlet air system will be divided up into nine quadrants (three by three grid). Each of the nine quadrants will contain a single automated dry bulb test temperature indicator (RTD) which will be read throughout the test. Four additional RID's will be used to measure dry bulb temperature downstream of the evaporative coolers at the compressor inlet.
6.2 Combustion Turbine Inlet Humiditv
One test psychrometer will be located in the center of and at the filter inlet The
psychrometer will consist of an RTD in a cotton wick, continuously wetted by a water
reservoir and aspirated by an induced draft electric fan. Relative and specific humidity
upstream of the evaporative coolers will be calculated from the wet-bulb and dry-bulb
temperature readings.
6.3 Barometric Pressure
A test absolute pressure cell will be located near the turbine shaft centerline elevation.
6.4 Turbine Exhaust!HRSG Inlet Pressure
Turbine exhaust pressure will be measured using test pressure transmitters connected to HRSG vendor provided static pressure probes located immediately downstream of the transition piece to the HRSG inlet.
PURCHASER Contract -Mar 21, 2011 Page 54 of! 08 Execution Document
6.5 Turbine Exhaust!HRSG Inlet Temperature
Turbine exhaust temperature will be measured with a temporary test grid of a minimum of sixteen calibrated thermocouples installed in the HRSG inlet duct through two - 3 inch wall ports. If special GT vendor supplied exhaust thermocouple rakes are installed for start-up and are available during the test, they may be used in addition to the grid. Exhaust temperature from the standard GT unit thermocouples or RID's will be recorded for reference.
6.6 Combustion Turbine and Duct Burner Fuel Flows
Fuel flows will be determined by measuring differential pressure across the existing calibrated orifice plate meter tubes. Test differential transmitters will be installed in parallel with the plant
, transmitters.
6. 7 Fuel Pressures
Pressure at the fuel flow metering orifices will be measured by a test static pressure
transmitter installed on the high pressure side of the flow orifice.
6.8 Fuel Temperature
Fuel temperatures will be measured by test RID's or thermocouples installed in a
thermowell located upstream of the fuel flow orifice meter tube.
6.9 Fuel Analysis
A minimum of two fuel samples will be taken by the owner during each test run.
Additional samples may be taken during the test run if unsteady fuel conditions are
suspected. One sample will be sent to a qualified lab for analysis. Fuel heating values
and specific gravity will be calculated from the lab analysis using properties in PTC 22.
The second sample will be retained by the owner as a spare.
If any party does not challenge the fuel sample results within a three-month period following the test, the fuel sample analysis results will be considered acceptable to all parties and the spare samples will be discarded.
6.10 Water Flow
Water flow will be calculated based on measured differential pressure across a flow
element, measured static pressure, and measured temperature. The discharge coefficient
PURCHASER Contract- Mar 21, 2011 Page 55 of I 08 Execution Document
for calibrated elements will be extrapolated to actual line Reynolds number.
6.11 Steam Quality
In some cases steam quality should be defined. Steam quality will be determined by measuring the sodium concentration in the drum water Cdw and comparing it with the sodium concentration in the wetted saturated steam C,w at the outlet of the drum. The difference between the unit and the ratio of concentrations C,w!Cdw will correlate to the steam quality.
6.12 Water/Steam Pressures
Static pressure transmitters will be connected in parallel with the plant gauges or transmitters on the high-pressure side of the flow elements.
6.13 Water/Steam Temperatures
Water and steam temperatures will be measured by K-type thermocouples or RTDs installed in test thermowells. .
6.14 HRSG Stack Gas Temperature
During the test, test probes consisting ofK-type thermocouples will be installed in each of the 4 EPA ports located in the stack. A minimum of twelve thermocouples will be installed. The thermocouples will be placed at the centroid of equal areas inside the stack.
7.0 EVALUATIONOFTESTRESULTS
7.1 Correction of Performance Guarantees
The tests will be conducted as close as possible to the guaranteed conditions; however, since it is not possible to operate exactly at design conditions, the guaranteed performance for each tested mode will be corrected to the test conditions using a computer code provided by the HRSG vendor. Actual HRSG performance will be compared to the recalculated guaranteed performance predicted by the computer program to determine ifthe HRSG has met all performance guarantees. Once the analysis of the test has been completed, the predicted parameter will be compared with the measured parameter. Any excess in steam flow or temperatwe on any pressure level can be traded for a deficit of flow or temperature on another pressure level on an equivalent energy basis down to a difference of zero. Once the tradeoffs have been completed, a test tolerance equal to test uncertainty will be applied to all guaranteed parameters. Any parameter falling within the test tolerance will not be assessed an LD or credit. Any parameter falling outside the test tolerance will be assessed an LD or credit equal to the difference between the measured/corrected parameter and the outside edge of the tolerance band.
Steam Tradeoff within the OEM steam turbine steam flow limits will be allowed using the following Formula:
1 lbHP steam = (EnthalpyHP steam- Enthalpy LP Turbine Exbaust)/(EnthalpyLP steam- EnthalpyLP Turbine Exhaust) lb LP Steam
1 lbHRH steam = (EnthalpyHRH steam- Enthalpy LP Turbine Exbaust)/(EnthalpyLP steam- EnthalpyLP Turbine Exhaust) lb LP Steam
No trade off from excess LP steam above 45,000 lblhr will be allowed.
The computer code should be provided to the owner at least six months prior to the test so that
it can be incorporated into the test procedure and used for uncertainty analysis of the test
procedure. The code will be subject to validation and approval by the owner. The code will
be based on actual unit design and accurately simulate changes in HRSG guaranteed
parameters across the range of expected operating conditions.
7:2 Test Tolerances and Measurement Uncertainties
·PURC:HASERContract- Mar 21,2011 Page 51 uf 108 · Execution Document
The performance of the HRSG will be evaluated based upon whether actual performance of guaranteed parameters fall within the test tolerance as described in the commercial terms and conditions.
A pre-test uncertainty analysis will be performed to verifY that the proposed test plan will provide results with an uncertainty that is less than the tolerance. If the uncertainty of any parameter exceeds the tolerance then the test plan will be revised to achieve a lower uncertainty or the tolerance will be increased to equal the calculated uncertainty.
The uncertainty associated with a corrected test value consists of the uncertainty of measured value itself along with the uncertainty of the variables from which it was corrected. Where individual uncertainties are not dependent on each other, the total combined uncertainty will be calculated as the square root-of-the-sum-of-the-squares (RSS) of the individual uncertainties. Where a dependency exists such that the RSS method would result in double inclusion of certain uncertainties into the combined uncertainty, the individual uncertainties will be broken down (proportioned) to eliminate the double inclusion.
The gas turbine exhaust flow will be determined using the uncertainty weighted capacity method based on flows determined from both the energy balance around the gas turbine and the energy balance around the HRSG. The uncertainty associated with the weighted value will be determined by the same method.
The gas turbine supplier will be responsible for providing the test team with all values necessary to perform a gas turbine energy balance. This includes, but is not limited to, gas turbine fuel flow, temperature and pressure, net power output, gross power output, fixed and variable losses, ambient pressure, wet bulb temperature, dry bulb temperature and power augmentation steam flow.
The uncertainty weighted method will be used only when the difference between the calculated gas flows are within the square root of the sum of the squares of the uncertainty of each energy balance method. Otherwise the reason for the discrepancy should be investigated and resolved or the test should be treated as invalid.
7.3 Calculations
7.3 .1 Fuel Flow
PURCHASER Contract-Mar 21, 2011 Page 58 of I 08 Execution Document
Fuel flow will be calculated from the test instrumentation associated with the fuel orifice meter provided with the gas turbine. Flow calculations will be based on the procedures outlined in ASME MFC-3M-1989 as follows:
where,
Gas mass flow Qb/sec) Units conversion constant
Orifice discharge coefficient Orifice beta ratio (dill) at flowing temperature Gas expansion factor referenced to upstream pressure Orifice plate bore diameter at flowing temperature (inches) Orifice differential pressure (inches H 20)
Pressure at upstream tap Qbmlff)
The dimensions of the orifice and pipe required in the above equation will be determined at the flowing temperatare as follows:
where,
Measured diameter of orifice (inches) Measured diameter of pipe (inches)
Coefficient of thermal expansion for orifice (in/in/0F), from Table E2 Coefficient of thermal expansion for pipe (in/in/0 F),
from Table E2 Temperature of flowing fuel (OF) Metal temperature when components were measured (OF)
PURCHASER Contract-Mar 21, 2011 ·Page 59 .of:l08 Execution Document
The fuel properties required in the flow equation will be calculated based on the test fuel analysis using procedures outlined in AGA report No. 8 per the "Detail Characterization Method". The orifice discharge coefficient will be taken from the calibration data (if available) or calculated from the appropriate equation in ASME MFC-3M-1989.
For natural gas as a fuel, the density of the gas at any given state will be calculated from the gas law equation as follows:
where,
ZxR.xT
p = Gas density at T and P (lbmlfl?) 144 = in2/fl? conversion factor
P = Gas pressure (psia) Mrgas = Molecular weight of gas (lbm/lbmole) determined from gas analysis
Z= Gas compressibility factor (calculated from AGA Report No.8) R = Universal gas constant (1545.35 (lbf-ft)/(lbmol-"R)) T = Absolute temperature of gas ("R)
The gas volumetric flow at line and standard conditions will be calculated from the mass flow as follows:
q, = qm
q - qm v- Pb
q, = Gas volumetric flow at line conditions (ft3/sec) qv= Gas volumetric flow at standard conditions (ftl/sec) qm = Gas mass flow (lb/sec) P/J = Density of flowing gas upstream of orifice (lbm/W) Ph = Density of gas at standard conditions (lbrn!fl?)
7.3.2 Water and Steam Flows
Feedwater and steam flows will be calculated using the appropriate flow meter equations from ASME Fluid Meters. For calibrated flow elements, the discharge coefficients will
PURCHASER Contract- Mar 21, 20Il Page 60 of I 08 Execution Document
be based on calibration results and will be extrapolated to actual line Reynolds number. For uncalibrated flow elements, the discharge coefficient will be calculated using the appropriate equations from ASME .MFC-3M-1989.
7.3.3 Stearn Quality
Stearn qualitY will be based on the ratio of sodium concentration is the feedwater and the water portion of the two-phase flow at the outlet as follows:
where,
Ys = Stearn quality
Cdw = Concentration of Sodium in the drum water (ppm) C,w = Concentration of Sodium in the steam wetted (ppm)
7.3.4 Combustion Turbine Exhaust/HRSG Inlet Gas Mass Flow
The exhaust gas mass flow will be determined by the following method.
• Energy balance around the HRSG
• Energy balance around the CT
The gas enthalpies are based on the NASA-Lewis tables and correlations. Fuel specific heat is derived from ASME PTC 22.
The general equation for the HRSG energy balance is as follows:
Where: Qgas,ln = HRSG inlet gas energy (Btulhr). Qdb!uel = Ductbumer fuel energy input (Btu/hr)
(Fuel lower heating value and sensible heat) Qw.ln =Energy of water entering the HRSG (Btulhr). Qgas,out = HRSG outlet gas energy (Btulhr). Qws,out =Energy of water and steam exiting the HRSG (Btulhr).
PURCHASER Contract-Mar21, 2011 Page 61 of108 Execution Document
Q, =Radiation and Convection Losses (Btu!hr) (To be provided by supplier)
7.3.5 Gas Side Pressure Drop
The gas side static pressure drop is taken as the static pressure (referenced to atmospheric) at the gas inlet to the HRSG.
7.3 .6 Other Parameters
Any other parameters which may be necessary for calculation of guaranteed test results will be measured or estimated with sufficient accuracy to achieve the required overall uncertainty of test results.
PURCHASER Contract-Mar 21, 2011 Page 62 of I 08 El!;ecution Document
8. References
PTC 3.1 - Diesel and Burner Fuels PTC 3.3 - Gaseous Fuels PTC 4.4 - Gas Turbine Heat Recovery Steam Generators PTC 19.1 -Measurement Uncertainty PTC 6R - Guidance for Evaluation of Measurement Uncertainty in Performance Tests
on Steam Turbines PTC 22 - Gas Turbines ASME MFC 3M- Measurement of Fluid Flow in Pipes Using Orifice, Nozzle, and
Venturi ASTMD 1945-91- Standard Method for Analysis ofNatural Gas by Gas
Chromatography* ASTM D 4809-90 - Standard Test Method for Heat of Combustion of Liquid
Hydorcarbon Fuels by Bomb Calorimeter, Intermediate Precision Method*
ASTM D 1480-91 - Standard Test Method for Density and Relative Density (specific Gravity) ofViscous Materials by Bingham Pychrometer*
ASTM D 445-94 - Standard Test Method for Kinematic Viscosity of Transparent and Opaque Liquids (Calculation of Dynamic Viscosity) *
AGA report No. 8 - Compressibility Factor of Natural Gas and Related Hydrocarbon Gases
"Measurement Uncertainty -Methods and Applications", Dieck, Ronald H., ISA Publication
PURCHASER Contract-Mar 21, zon Page 63 of! OS. Execution Document
EXHIBIT J- NOOTER/ERIKSEN TECHNICAL PROPOSAL 1507-05 -Final-
March 21, 2011
TABLE OF CON1ENTS 1.0 See Contract portion ....................................................................................................... 65 1.2 See Contract portion ............................................................ Error! Bookmark not defined. 2.0 See Exhibit A .................................................................................................................... 65 3.0 Constructability Advantages and Features .................................................................. 65 4.0 Customer Interfaces ......... u ............................................................................................. 66 5.0 Technical Description .......................................................................... -.... -.. -.. ~ . .-..... -.......... u•• 71
5 .I Process Design Features ............................................................................................... 71 5.2 Mechanical Design Features ......................................................................................... 71 5.3 Design Codes ............................................ ; ............. , ....... ; .............. , .............................. 73 5.4 Major Components ...................................... : ................................................................. 74
6.0 Trim List ........................................................................................................................... 82 6.1 ASME Code Section I Required Vnlves nnd Trim ....................................................... 82 6.2 Nooter/Eriksen Staodard Valves and Instrumentation .................................................. 83 6.3 Project Specific Scope ............................................ ; .......................................... , .......... 84 6.4 General Trim & Instrumentation Comments ................................................................ 86
7.0 Design Basis ..................................................................................................................... 87 7.1 Contract and Specifications .......................................................................................... 87 7.2 HRSG Perfonnance ...................................................................................................... 87 7.3 MechanicaVStructural Design ........................ , ................................................... , .......... 88 7.4 Instrumentation and Valves .......................................................................................... 88 7.5 Miscellaneous ............................................................................................................... 89
8.0 See Exhibit E ..................................................... ~ .. ~.~ .... · ...................................................... 91 9.0 Required Information from Greenfield South Power ................................................. 91 10.0 Field Erection Information ............................................................................................ 92
10.1 General .. ! ....... , ....................................................................................................... u.-•••• :o· ....... 92 10.2 Pre-Erection Meeting ............................... , ....................................... , ........ , .. , ............ , .... 92 10.3 Technical Field Assistaoce .................................. , ........................................................ 92 10.4 Training Classes ............................................... , .. ;, ... ; ....... ,, .•. , .• , ................ ;;, ................... 92
11.0 Aftermarket Services ...................................................................................................... 93 12.0 Clarifications and Exceptions ........................................................................................ 94
12.1 Commercial .................................................... ,,.; ..... ;,; ..... ; ..................... ,., ....... ., ...... ,.,., •. 94 12.2 Technical ....................................................................................................................... 94
13.0 Appendices 13.1 N/E Staodard Blowdown Tank Design and Layout 13.2 N/E HRSG Thennal Data Sheets 13.3 N/E HRSG GA Drawings 13.4 N/E HRSG P&ID's 13.5 N/E HRSG Trim List 13.6 N/E HRSG-GSPC Mechanical Interfaces 13.7 N/E HRSG Component Dimensions and Estimated Shipping Weight
PURCHASER Contract -Mar 21, 2011 Page 64 of 108 Execution Document
1.D See Contract portion
2.D See Exhibit A
3.D Constructability Advantages and Features
" Roof casings are shop installed on modules except in some cases where the duct burner is part
of the first or second modules box.
" Packing glands/expansion joints on all pipes penetrating through the roof casings are shop
installed.
" Top supports are shop installed between all modules and the roof casings.
" Lower evaporator manifolds that connect to evaporator lower headers are shop installed.
" Upper gas bypass sealing baffles are shop installed.
" Tube vibration supports are shop installed.
" Acoustical vibration baffles are shop installed.
" Entire modules (up to 250 tons) are shipped as one bundle.
" No major large bore pressure part welds are required inside the HRSG casing
" No large return bend pipe welds are necessary to connect loose harp sections of economizers of
other designs.
" Main vertical structural steel columns.are prefabricated and attached to casing panels in the
shop.
" Steel base/sole plates for casing columns are welded on in the shop.
" Large bore interconnecting HRSG piping spools are shop prefabricated in large 2D spools.
" No temporary support steel or trusses need to be removed after setting of modules in the HRSG
casing
Distribution Grid • Panels bolted together in field rather than welded
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4.0 Customer Interfaces
4.1 General Terminal Point Information
The following list includes the points at which Nooter/Eriksen terminates the scope of supply. Mating flanges, gaskets and bolts, and continuing scope beyond these points are to be furnished by Greenfield South Power or others.
Items not specifically listed will be terminated local to equipment.
All of the piping terminal point interfaces will be set by NIE, taking into account any elevation requirements in the Customer specification. Any changes by the Customer to these Interface locations will change the HRSG piping layout and any resulting schedule impact (as well as potential material costs) will be provided for as a change order to the cor:rtract.
Founda.tion
Turbine Exhaust Gas Ductwork
Inlet flange of HRSG inlet duct/inlet expansion joint Outlet of main exhaust stack
Structural Steel Work
Underside of column base plates (anchor bolts and nuts, sole plates, shear plates, embedments, grounding lugs and grouting by others)
Duct Burner (See Note 2)
Fuel inlet on burner skid Outlet of all burner fuel atmospheric vent valves Connection to firing duct view ports
Steam Outlets
Outlet of last Nooter/Eriksen supplied valve in main steam line at top of HRSG Reheat piping interface is at the top of the HRSG
Feedwater
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Feed Pump Suction
Outlet of stop valve at the top of the HRSG
Small Bore Connections
See Section 4.3 for detailed discussion of the small bore interfaces including blowdown, chemical feed, sample location, and drains.
Vents
Outlet of vent isolation valve(s) routed to nearest platfonm (See Note 2)
Start-Up Vents
Safety Valves
Factory supplied instrument connections
Flow Elements
At equipment terminals (supplied loose for mounting into Greenfield South Power's piping)
Test Connections
At thenmowells or outlet of isolation valves on steam/water side (See Note 2)
Capped connections on gas side
Emissions Monitoring
4.2 Layout assumptions for Piping, Auxiliaries and Slowdown tank
GSPC large bore pipe line will tenminate at the mutually agreed upon locations as shown in Appendix 13.6. N/E will extend the large bore tenminal to match the HRSG large bore tenminal point to the preferred locations. It is understood that the preferred terminal locations may be modified upon mutually agreed between Purchaser and N/E during HRSG detailed design process.
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Ammonia skid, burner skid and blowdown tank (if required) are located within 12 It of the HRSG casing and the blowdown tank Is located close to the HP evaporator. the attached Layout drawing GA-01 L-A shows the Conceptual Locations for the auxiliary equipment.
Access doors platforms (if provided) are to be located on the oppos~e side of the HRSG small bore piping
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4.3 Small Bore Piping Interfaces
N/E will provide standard routing lanes for small bore piping where no large bore pipe or customer equipment will be allowed to interfere. (See blowdown tank description in the Appendix). These lanes will eliminate interferences and allow for quick and easy layout of the small bore piping.
Small Bore Piping Une Scope Definition All Coil Drains Routed to blowdown tank. All low point oiPin!l drains Tenninates at open funnel at too of unit Water Column drains Routed to blowdown tank Note 1 Drain pot drains- top of unit Routed to blowdown tank Note 1 Intermittent Blowoff Pioin!l Routed to blowdown tank. Note 1 Continuous Slowdown Piping Routed to blowdown tank· Note 1 Lower HP SHand RH drain Routed to blowdown tank PSV drain connections Tenninates atopen funnel at top of unit PSV valve bodv drain Tenninates at Qllen funnel at too of unit Start-up vent drain Terminates at open funnel at top of unit Hydrptest vent Terminates at last stop valve near equipment connection
point (Note 3) Chemical feed Tenninates at valve close to feedwater piping into drum
(Note2l Chemical clean Tenninates at blind flange connection on downcomer (Note
2) .
Steam sample Tenninates at valve near eQuipment (Note 2) Level gage drain Routed to blowdown tank. DesiJ!)erheater water line Terminates at valve near desuoerheater control valve Silencer Drains Terminates at open funnel at too. of unit.
Notes: 1. Upper lines are tied together by pressure level at the top of the unit before routing down to
blowdown tank. 2. Does not route to grade 3. Does not route to platfonn or other access point.
General Notes:
Coil drains are manifolded together per coil after the first isolation valve. After the second valve, the drains are manifolded together by pressure level and routed to the blowdown tank.
Due to layout considerations, there may be multiple funnel locations.
All piping tenninal points 2Y." NPS and larger will be butt-welded. All piping tenninal points 2" NPS and smaller will be socket welded.
Small bore piping will be provided in random lengths by Nooter/Eriksen for field routing and installation in the field by the erection contractor.
While small bore piping should be considered field routed, N/E will include all small bore piping in the 3- dimensional model for suggested routing with the exception of miscellaneous upper drains that are routed to an open funnel. For these drains a standard piping detail will be provided.
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Pipe support locations and drawings will be provided for all small bore piping located in the specified lanes. All small bore piping routed Individually to the lanes will be per N/E standard small bore support guidelines and will be field located by the erector in accordance with those instructions.
4.4 Pipe Stress Analysis and Support
4.4.1 Pipe Stress Analysis
The pipe stresses and movements at the large bore interface will be addressed in the following way: (1) low temperature steam and water piping will be rigidly fixed at the interface; (2) The high temperature steam lines (HP steam outlet, Reheater inlet and outlet) will not be fixed at the interface point. Nooter/Eriksen will provide a support concept to Greenfield South Power along with the pipe layout, movements, and allowable loads at the coil headers for analysis of the complete line by Greenfield South Power; (3) three weeks after receiving the information from Nooter/Eriksen on the high temperature lines, Greenfield South Power should provide detailed design information, including required pipe supports. Nooter/Eriksen will work with Greenfield South Power to finalize the analysis for the high temperature steam lines with a support concept that is mutually agreeable.
N/E provides a detailed stress analysis only on the following small bore lines:
o All HP Superheater and Reheater drain lines only to a fixed support point. From that location the line will be supported using the standard support guidelines.
o Desuperheater lines to a fixed point.
The following additional lines are given a general check for flexibility: o Slowdown piping o Intermittent blowoff piping o HP Superheater and Reheater drains from PSV and Vents to blowdown tank.
The model generated for these lines may only be a partial model to insure the proper flexibility and dead weight support. For all other small bore lines, N/E has found ~ unnecessary to perform a detailed model analysis and instead these lines are reviewed with N/E standards for dead weight, internal pressure at design temperature and thermal expansion.
4.4.2 Large Bore Pipe Support
GSPC will provide the loading information for each large bore pipe (HP, IP, HRH, CRH, LP steam, HP FW minimal flow, IP FW, condensate). NIE agrees to design the HRSG structural steel to support the above LB pipe along the side of the HRSG per the loadings provided by GSPC.
5.0 Technical Description
5.1 Process Design Features
The heat recovery steam generator will be designed to meet the following performance and exhaust gas pressure drop with optimal heating surface and mechanical design.
Steam production will be:
HP Reheat/IP LP
588,950 lbs/hr at 1843 psig and 1052 oF 626,040 lbs/hr at 423 psig and 1052 oF 39,990 lbs/hr at 48 psig and 620 °F
with supplemental firing of 237 MMBTU/hr (LHV) as described on the enclosed HRSG Performance Guarantee.
Gas side static pressure drop from the inlet of the heat recovery system to the stack exit will be: 14.3 inches W.C. at the fired design point, 86 oF ambient day.
Performance cases used in the design of the HRSG are shown in Attachment 1 - HRSG Heat Balances .. Any additional modes of operation [combustion turbine (GT) part load, GT steam injection/dry operation, other ambient temperatures] may impact the design of the HRSG and should be specified by Greenfield South Power.
Supplemental firing of 241.5 MMBtulhr (LHV) to an exhaust gas temperature of 1392 oF will be utilized to achieve the maximum production of 587,020 lbs/hr of HP steam at 95 F ambient condition.
The duct burner firing will be limited so that the maximum duct burner duty is limited to 250.0 MMBtu/hr (LHV). This maximum duty will be achievable at a maximum ambient condition of 95 "F. At higher ambients, the burner duty will be limited to less than this maximum level based upon a limitation on the HP Superheater #1 outlet temperature of 980"F.
Supplemental firing will be allowed at combustion turbine full load operation only. The duct burner firing will be limited so that the reheater/superheated stearn temperature exiting HP Superheater #1/Reheater #1 does not exceed 980 /1115 oF. Also, the duct burner firing will be limited to a maximum duty of 250.0 MMBtu/hr (LHV).
The HRSG will be designed on the basis that the reheater will be operated wet with steam flow at all times, requiring a conditioning station (supplied by others) to provide steam to the reheater coil during start-up or steam turbine bypass operation. The conditioning station takes steam from the HP superheater outlet and delivers it to the reheater inlet at normal cold reheat conditions.
Cascading blowdown will be provided. The HP continuous blowdown will be routed and flashed to the IP steam drum. The drum solids are then removed by the IP continuous blowdown, minimizing the total system blowdown and increase the IP steam genetation. Increased IP steam flow is not reflected in the performance information provided.
The filnergy rfilcovered in the LP evapprator will be used to heat the condensate and/or make-up water and to provide export steam: The feedwater pump(s) will be fed from the LP steam drum, which is c:wersized .to provide 5 minute~!' of retention time for all the unfired feedwater flow.
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It is assumed that the water supplied to the HRSG is deaerated/has less than 20 ppb 02.
The HRSG has not been designed to operate with desuperheater failure. If the superheater design conditions are exceeded, the combustion turbine should be adjusted to bring the steam temperature within specified limits.
It is recommended that the inlet feedwater temperature be above the sulfuric acid dewpoint of the exhaust gas to prevent corrosion of the heating surface due to the sulfur present in the exhaust gas. For combustion turbine fuels, such as natural gas, that contain trace amounts of sulfur the feedwater temperature will be above 140'F (SO'C) during start-up and above 130'F (54.4'C) for base load operation. The sulfuric acid dewpoint of other combustion turbine fuels can be estimated based upon the H20/S0a concentration in the exhaust gas.
5.2 Mechanical Design Features
The unit(s) will be of the Modular HRSG construction that utilizes shop fabricated heat transfer modules, which are designed as large as practicable within shipping limits available for truck or rail deliveries. The modules will be shipped with the roof casing panels and roof structural steel attached. Insulated casing with integral liner and structural steel for the side walls and floor will be shop fabricated in large panel assemblies.
Modular fabrication of the HRSG maximizes labor performed under carefully controlled shop conditions and minimizes field labor.
Vertical tubes in a top supported unit provide for unrestricted downwand expansion.
The HRSG is of an all welded pressure part construction.
The HRSG is a natural circulation boiler design. Boiler circulation is maintained by the natural buoyant forces of the steam. Buoyant force is greatest in tubes where the heat flux is highest; water flow is strongest in areas where it is most needed. A circulation pump and the corresponding controls are not required so electric power is conserved and maintenance costs are lowered.
The tubes are in a staggered pitch arrangement to provide optimal heat transfer within the gas side pressure drop restrictions.
Tube diameter and spacing have been specifically designed to provide optimal heat transfer and fluid velocity in each tube bundle.
All HRSG components are fully drainable.
Maximum fin density is 7 fins per inch. Fins are serrated, high frequency, and continuously welded. Fins on alloy tubes in HP superheater and reheaters will be 409SS while all other fins will be carbon steel.
The HRSG will be designed in accondance with ASME Section I Code, 2007 ed~ion. The equipment will be designed per the project site conditions defined by Greenfield South Power, Nov 19, 2009. Greenfield South Power is responsible to inform N~oter/Eriksen of local building code requirements that exceed these requirements.
Intermediate tube supports will be included to eliminate excessive tube vibration; longitudinal baffles will be used to eliminate audible acoustic resonance where necessary.
A specified HRSG start-up rate in terms of 'I min in the steam drum will be calculated to meet the intended service life of the unit. The start up is controlled by the rate of pressurization in the HP drum by venting steam to the atmosphere or to the condenser, or by limiting the CTstartup rate until the steam
(
turbine is on line.
The external casing will be provided shop primed. Finish painting, if required, will be provided by others after erection.
A freeze protection system is reeommended in cold climates to protect.the HRSG during down times. Nooter/Eriksen is providing steam sparglng connections to provide heat input to the unit A stack damper has also been included as noted in tne Scope of Supply. Stack insulation as high as the damper is recommended and will be supplied and installed by others.
5.3 Design Codes
Nooter/Eriksen's equipment will be designed in accordance with the following codes and standards unless otherwise stated. The appropriate edition will be decided with Green~eld South Power at contract award. It is Greenfield South Power's responsibility to specify any add.itional codes or standards that should govern the design. Additional codes or standards will be reviewed for any possible impact to the enclosed offering.
N/E will design and certify the HRSG to CSAB51 and will be responsible for the registration of a HRSG CRN (Canadian Registration Number) issued by the TSSA (Technical Safety and Standard Authority' of Ontario, Canada.
5. 3. 1 Boiler Components
Basic Design Codes: ASME Section I - Power Boilers ASME Section VIII, Division 1 -Pressure Vessels ANSI B31.1 - Power Piping
All appropriate ASME Code Cases and Interpretations acceptable to local jurisdictions
Related codes referenced in the above-mentioned codes: ASME Section II - Materials
Part A- Ferrous Material Specifications Part C- Specifications for Welding Rods, Electrodes, and Filler Metals Part D - Properties (Customary)
Section V - Nondestructive Examination
Section VII - Recommended Guidelines for the Care of Power Boilers Section IX- Welding and Brazing Qualifications
ANSI Specifications: 816.1, 816.3, 816.5, 816.9, 816.11 B16.10M, 816.15, 816.25, 816.28, 16.34
5.3.2 Structural Design Codes
AISC LRFD: AISCASD: ASTM:
"Load Resistance Factor Design" (Main Structural Frame Design) "Allowable Stress Design" A6, A36, A53, A 106, A 193, A242, A325, A490, A500, A572, A588, A673
G3106 SM490YA G3106 SM490YB G31 06 SM520B
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EN:
BS:
DIN:
GB:
AWS- D1.1 AWS-D1.3
5.3.3 Building Codes
G3106 SM520C G3106 SM570 G3101 S$490 G3106 SM400A G31 01 SM400C G3106 SM490A G3106 SM490C
10025 S355JR 10025 S355JO 10025 S275JR 10025 S275JO
4360 Gr50B 4360 Gr50C 4360 Gr43B 4360 Gr43C
17100 St 52-3 17100 St 50-2 17100 St 37-2 17100 RSt 37-2
GB 700-0235 (all grades) GB 700-0195 (all grades) GBrr 1591-0345 (all grades)
One of the following will be used:·
UBC - Uniform Building Code
4360 Gr43A 4360 Gr50A
ASCE 7 - Minimum Design Loads for Buildings and Other Structures IBC -International Building Code OBC-2006- Ontario Building Code
5.3.4 Stack Design
5.3.5 Instrument and Controls
Basic Design Code: ASME Power Boiler Code Section I
Related Codes Referenced by the above Code for valves and piping:
ANSI Specifications: B31.1, B16.5, B16.10, 816.11, B16.34, B16.36 Codes for Trim items:
ASTM Specifications: A105, A182 ISA for instrumentation devices, drawings, and specifications NEMA for electrical enclosures
5.4 Major Components
5.4.1 Pressure Parts
5.4.1.1 Superheaters
Tube diameter, spacing, and flow circuiting of!he superheaters will be carefully selected to provide good flow distribution and effective cooling of the superheater tubes.
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Intermediate and low pressure superheaters may be located as part of a first or last row of an evaporator.
The high pressure superheater will contain an interstage desuperheater in order to provide good final steam temperature control and ensure complete evaporation of the spray water.
The intermediate/low pressure superheater outlet temperature will be uncontrolled.
5.4.1.2 Reheater
The high pressure superheater and reheater modules will consist of multiple coils that are arranged in parallel relative to the turbine exhaust gas flow to minimize the effects of non-uniform gas flow or temperature distribution.
The high pressure superheater and reheater modules will consist of separate coils that are alternated longitudinally to the gas flow in order to obtain the proper outlet steam conditions.
Tube diameter, spacing, and flow circuiting of the reheater will be carefully selected to provide good flow distribution and effective cooling of the reheater tub<l.s.
5.4.1.3 Evaporators
The evaporators will be vertical tube, natural circulation steam generators. Vigorous circulation and effective cooling of the tubes will be ensured by the use of external risers and downcomers.
The evaporator tubes will be manifolded into upper and lower headers. Individual tubes will be welded into the headers.
5.4.1.4 Steam Drums
The remote steam drum(s) will ship fully assembled with all nozzles and saddles ready for final installation in the field.
The drum will contain a 12" x 16" manway in each end and will contain steam outlet, feedwater inlet,
safety valve(s), water level indicator(s), continuous blowdown, and instrument nozzles as required.
The HP Drum will be provided with two double yoke manway covers with spring washers and Chesterton gaskets for easier manway closure and installation.
Steam/water separation will be accomplished by primary inertial separators and secondary chevron type separators. The drum internals will also include headers for feedwater distribution. Chemical feed will be connected to the feedwater inlet piping for better mixing and distribution.
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UOUID LEVEL
CHE:VRON DRAIN
The drum will be insulated in the field by others. Since this will be a horizontal vessel, insulation lagging studs will not be required or provided.
5.4.1.5 Economizers
The tube diameter, spacing, and flow circuiting of the economizers will be carefully sel~ted. to provide good flow distribution and effective water velocHies. Some economizer modu.le.s will contain independent water flows for different pressure services arranged in parallel relative to the turt:Jine exhaust gas flow.
Each economizer that feeds a steam drum (with no control valve downstream) is designed such that the
last 1Yz rows in half-circuit layouts and the last 2 rows in full-circuit layouts carry water upflow, allowing
free venting of steam bubbles, if generated, into the drum via the outlet header and the interconnecting
piping. In addition, the header that precedes the last downflow section is orificed at each tube for proper
flow distribution.
The unit will be fully drainable through the lower headers as shown in the drain system section (3-D drawing) of the proposal. The headers allow access to the tubes for maintenance and to permit plugging of a single hairpin (pair of tubes) In the future if necessary.
5.4.1.6 Deleted
5.4.1. 7 Feedwater Preheater
Tube diameter, spacing and flow circuiting of the feedwater preheater will be carefully selected to provide good flow distribution and effective water velocities. Special care will be taken to minimize the effect of any steam bubbles generated during start-up or upset conditions.
The unit will be fully drainable through the lower headers as shown on the enclosed drawing. These
headers allow access to the tubes for maintenance and to permit plugging of a single hairpin in the future if necessary.
The coil will be constructed of carbon steel tubes and built in accordance with ASME Section I Code. Feedwater to the preheater coil shall not exceed 20 ppb oxygen.
5.4.1.8 Deleted
5.4.1.9 Piping. Valves. and Instrumentation
A complete set of large bore terminal and interconnecting piping spools between the heat transfer coils
will be furnished. Piping will be fabricated in 2D spools with ends cut and beveled in the shop for final
welding in the field except when field trim is provided. All valves will be shipped loose for protection during
transport. External insulation and/or painting are not included. Piping supports or anchors for
Nooter/Eriksen-supplied piping will also be included. The geometry of the piping will be designed to
accommodate thermal expansion during operation.
All piping terminal points 2%" NPS and larger will be butt-welded. All piping terminal points 2" NPS and smaller will be socket welded.
All piping 2" diameter (NPS) and smaller (small bore) will be provided in random lengths by Nooter/Eriksen for routing and installation in the field by the erection contractor. Nooter/Eriksen will supply suggested small bore piping routing.
Valves and instruments will be furnished as described in Section 6. All trim list items will be furnished and shipped loose with the equipment for field installation by others. Nooter!Eriksen reserves the right to substitute trim of equal performance.
5.4.1.10 Start-Up Spare Parts
The following spare parts for start-up and commissioning are included:
• Three (3) sets of manway gaskets for each steam drum -One (1) temporary level gauge glass for each pressure level -Feedwater check valve gaskets -Steam non-return valve gaskets -Chemical clean kits for cage guided control valves -Steam blow nozzles (if required for desuperheater)
5.4.2 Ductwork
5.4.2.1 Inlet Expansion Joint
One fabric expansion joint will be furnished for installation at the combustion turbine exhaust outlet.
The e)Cp:;!nsion joint(s) will be designed to withstand the specified combustion turbine exhaust temperatures, a~d will be designed for axial, lateral, and angular displacements imposed by the combustion turbine plenum and the HRSG at the interface.
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The expansion joint(s) will be constructed with a fabric belt on the outside between two duct flanges. The inlet flange will be designed to withstand the high temperatures, while the outlet flange will be isolated from the hot exhaust gas and will be designed for the same external temperature as the HRSG inlet dueling. Insulation will be located between the fabric belt and the internal stainless steel liner. The expansion joint(s) will have bolted flange connections on both the turbine exhaust and HRSG inlet sides and require field assembly and insulation.
5.4.2.2 Distribution Grid
A flow distribution grid will be included in the inlet duct, if required to improve exhaust gas flow distribution. A flow model test and analysis are done on all units with a duct burner utilizing turbine exhaust information supplied by Greenfield South Power to determine the necessity of a distribution grid.
5.4.2.3 Deleted
5.4.3 Casing
Nooter/Eriksen's standard insulated casing design utilizes a cold, gas tight outer casing to virtually eliminate thermal expansion of the casing and prevent rapid thermal transients from overstressing and cracking the casing. The casing will be internally insulated and lined with a special floating liner that is free to move to accommodate thermal growth without distortion or warping In high turbulence areas, each liner plate will be supported on its perimeter with a rigid structural system, and floating channels will be added to the perimeter of each liner plate for additional support.
The external casing surface will be sandblasted in accordance with SSPC-SP6 and prime painted with a coat of inorganic zinc primer.
The liner material will be dictated by the exhaust gas temperatures. Liners are a minimum 12 or 16 gauge depending on the area of turbulence.
The internal insulation may be installed in two layers with staggered seams for insulation thickness greater than 2'.
The insulation thickness is based on maintaining an average casing temperature of 140°F at an ambient temperature of 80°F. The calculation for surface temperature and casing/dueling insulation thickness is based on the use of a non-aluminum bearing finish coat.
Access to the gas path is provided by 18" x 24" bolted, gasketed doors, which are provided with a grab bar and a swing davit.
Inlet dueling will be supplied from the interface point to the main HRSG casing.
The inlet duct and main HRSG casing will ship as shop insulated and lined panels with structural steel attached.
The primary casing panels have the main structural columns attached to them. These panels are to be set on their foundations, bolted/welded and braced in their final positions. The field seams between
casing panels are seal welded at the outer casing from the outside of the system.
Floor beams are fit-up and held in position with bolted connections. The secondary floor casing is set in place and seal welded to the adjoining primary floor casing from the liner side of the casing panel. The roof beams are sent to the field with the casing, insulation and liners shop installed.
The roof casings are shop installed onto the modules unless noted otherwise on drawings. Field seams are required between the adjacent shop installed module roofs and between the shop installed module roofs and the sidewall.
5.4.4 Platforms, Walkwavs and Ladders
Platforms, walkways, and ladders will be included to provide quic~ and easy aCl)ess for operation and normal maintenance. A main deck platform will provide access on top of the casing and around the steam drums. Accessfrom grade to the main deck is provided by a stair tower and an egress ladder. Ladder and platform access frOmthe main deck is provided to the CEMS ports on the exhaust stack. The stairtower will be independently supported and laterally braced to the HRSG. Platforms will be a minimum of three feet wide and designed to meet Federal OSHA requirem!'lnts. Design live loading will be 100 psf. Platform and stair grating will be hot dipped galvanized to prevent corrosion. Ladders, handrails and support steel will be shop primed.
All personnel protection, platforms, and ladders ~ill be shipped loose for installation in the field by others.
Platforms will be provided with the superstructure and grating attached. The superstructure maximum dimensions are approximately 1 0' wide by 45' long. This dimension decreases to 7'3" by 38' if the platforms are required to be containerized. The substructure of the platforms will be shop fabricated as much as possible up to the maximum shipping limitations. Platform substructures will require some field welding and/or bolting.
5.4.5 Exhaust Stack Expansion Joint
The stack expansion joint will utilize a fabric belt and will be attached between the last module and the stack breaching. The expansion joint will be designed for axial, lateral, and angular displacements caused by the expansion difference between the internally insulated casing and the uninsulated stack.
5.4.6 Exhaust Stack
The exhaust stack is self-supporting uninsulated carbon steel. A caged ladder will be provided for access
to a 4 foot wide, 360° EPA platform, from which four (4) flanged EPA sample connections spaced 90°
apart will be accessible. Expanded metal personnel protection will be located at the base of the stack to a
height of 8' above grade. Personnel protection will also be placed at the EPA ports to a height of 8 •
above the platform. All personnel protection, platforms and ladders will be shipped loose for installation in
the field by others.
Breaching will lead from the HRSG outlet to the stack inlet, and will consist of a gas tight casing reinforced with structural stiffeners. The uninsulated breaching will include personnel protection to 8' above grade in areas where there is access.
PURCHASER Contract- Mar 21,2011 Page 79 of108 Execution Document
The external stack surface will be sandblasted in accordance with SSPC-SP6 and prime painted with a coat of inorganic zinc primer.
The stack will ship in 10' Tall x 120' sections for field assembly.
A damper will be provided for the main exhaust stack to retain heat in the HRSG. The damper will be designed to minimize leakage when closed and will be located just above the stack breaching. A 4 foot wide access platform will be provided for access to the damper.
External insulation will be required on the stack to the height of the damper and on the stack breaching I outlet duct. External insulation to be supplied and field installed by others.
5.4.7 Acoustical Treatment
Sections of the HRSG will have increased casing wall thickness to reduce both near and far field noise.
HRSG stack silencing baffles will be supplied to reduce the stack lip sound power levels to 101 dBA from the HRSG Stack lip.
5.4.8 Deleted
5.5 Auxiliary Equipment
The following is a recommended conceptual layout for the HRSG auxiliary equipment.
5.5.1 Supplementary Duct Burner
A duct burner system will be provided for supplementary firing, using excess oxygen present in the turbine exhaust gas to burn natural gas, raising the exhaust gas temperature and increasing steam output.
The duct burner will be designed and constructed within the guidelines of the NFPA and will feature burner elements mounted in a structural steel framework integral to the HRSG. Each burner system will include one or more main burner elements, pilot burners with ignitors, and flame scanners. The burners will be designed to produce a stable flame throughout the turndown range (10:1 for gaseous fuels). Fuels must be supplied at proper pressures and must be regulated by Greenfield South Power.
The burner and associated skid will be provided with a non-hazardous area classification with NEMA 4, Enclosures.
All required piping and instrumentation for control of the main and pilot fuels will be provided on a factory assembled, wired, and tested, free standing skid that will be designed for field installation near the duct burner assembly. Piping from the skid to the burner elements is supplied by Nooter/Eriksen with the assumption that the burner skid will be located no more than 15' from the burner.
The Burner Management System (BMS) will be provided by a proprietary logic system contained within a factory assembled, wired, and tested, control enclosure attached to the piping module. The BMS will include all safety interlocks and indications required by NFPA and will be designed for operation via remote electrical controls. Burner firing rate signals are to be provided by Greenfield South Power's DCS.
The Burner Management System (BMS) will be provided by Greenfield South Power's DCS. Electrical components located on the piping module will be factory wired to terminal strips contained within an
electrical enclosure attached to the piping module. Burner firing rate signals will be provided by Greenfield South Power's DCS.
The duct burner firing will be limited by the steam temperature so that it does not fire above the HRSG design conditions.
Ancillary equipment supplied with the burner will include the following:
One scanner cooling/purge air blower(s) (each sized for 100% capacity) including inlet air filter silencers
A firing duct w111 be located immediately downstream of the burner to provide thE) proper gas velocity for good mixing of fuel and combustion air a~d \ldequate volume for complete combus.tion. The duct is designed to prevent flow recirculation an.d poor mixing near the walls. The firing duct will include view ports for burner runners, pilots and flame lengths.
5.5.2 Deleted
5.5.3 Deleted
5.5.4 Deleted
5.5.5 Deleted
5.5.6 Deleted
5.5.7 8tmosgheric Slowdown Tank
A vessel designed to accept boiler water flows from intermittent blowoff of each pressure vessel and the continuous blowdown of each pressure system will be provided. All flash steam is vented to atmosphere. Cooling water will be required to cool the water to an acceptable discharge temperature.
The tank will be designed in accordance with the ASME Boiler and Pressure Vessel Code Section VIII, Div.l.
It will include separate inlet nozzles for each pressure level of the HRSG as well as a cooling water inlet nozzle, vent connection, a drain connection and water level, pressure and temperature instrumentation.
5.5.8 Deleted
5.5.9 Deleted
5.5.10 Drain System
Drain lines are manifolded together before penetrating through the HRSG floor to minimize casing penetrations.
6.0 Trim List
The valves and trim supplied by Nooter/Eriksen include ASME Code Section I requirements, Nooter/Eriksen standard recommended instrumentation and valves, and any scope of supply as required per the specification.
A detailed list of boiler and piping trim for the project is found in Appendix 13.4.
6.1 ASME Code Section I Required Valves and Trim
6.1.1 Pressure Safety Valves
ASME requires a minimum of two relief valves on a pressurized steam system with capacity for relief of full steam production. PSV's set pressures are set to avoid simmering or premature release, which would reduce the life of the PSV.
6.1.2Feedwater Stop Valve
This gate valve serves as an isolation valve between the feedwater pumps and the entrance Into the HRSG piping.
6.1.3Feedwater Check Valve
=s·····-····· ····--·····-------~---------------------··--·-···---------------------------------- --------- ------- -----------···--------------------
This valve prevents any back flow of water from the HRSG to the feedwater feed pumps, which could result in damage and also serves as the code break at the HRSG inlet.
6.1.4 Blowoff Valves
These valves are designed especially for blowoff operation. For the HP system two globe-like valves are
supplied while for the IP and LP systems, an angle valve followed by a globe-like valve will be provided.
These valves serve as a connection to allow removal, on an intemnittent basis, of accumulated
suspended solids in the evaporator.
6.1.5Continuous Slowdown Valves
These valves are located on the steam drums and consist of an isolation valve and an angle regulating
valve. They provide a regulated connection for continuous removal of dissolved solids from the drum
water to provide proper water chemistry and the desired steam purity
6.1.6 Steam Stop Yalve
This gate valve serves as the ASME code break as well as an isolation valve between the HRSG and the output recipient.
6.1. 7 Isolation Valves
These small bore valves serve as a means to isolate an instrument from the working fluid and include, but are not limited to: pressure gauges, drum level transmitters, water gauges, water columns, pressure transmitters, sample points, and nitrogen blanketing.
6.1.8 ASME Reauired Instrumentation The instrumentation consists of a steam drum pressure gauge and siphon, and two local level indicators (level gauges) or one local level indicator plus two (2) remote level indicators (level transmitters). Nooter/Eriksen's standard is to provide two sets of connections for level transmitters and one local level indicator.
6.2 Nooter/Eriksen Standard Valves and Instrumentation
6.2.1 Drain Valves
These small bore globe valves are provided for isolation and water removal from the HRSG tube bundles and instruments (i.e. level gauges). Drain valves are typically supplied for every lower header in the HRSG, the water columns, and the level gauges. A second isolation valve is also provided but it may be a common valve for several isolation valves. The Superheater/Reheater common drain valve is provided with a motor operator.
6.2.2Hydrotest Vent Valves
PURCHASER Contract-Mar 21, 2011 Page-83 of 108- Execution Document
These valves are typically paired globe valves provided for the removal of air at piping high points.
6.2.3Chemical Feed Valves
These valves consist of an isolation valve and check valve that provide a connection for the introduction
of water treatment chemicals into the feedwater.
6.2.4Thermocouples with Thermowells
If not otherwise specified by Greenfield South Power, Type K thermocouples will be supplied. A dual element thermocouple and thermowell will be supplied for each pressure level for the following temperature measurements:
Exhaust Inlet Temperature (2) Exhaust Stack Temperature Feedwater Inlet Temperature Outlet Temperature of each Section
6.2.5Steam Pressure Gauge A pressure gauge is provided at the steam outlet of a given pressure level if it contains a superheater,
6.2.6 Water Column
A water column is provided on all steam drums except for integral deaerator drums. The water column
has HHWL, HWL, LWL and LLWL switches if required by Greenfield South Power's specification.
6.2.7Miscellaneous Casing Connections
There are various casing connections that are standard with a Nooter/Eriksen unit and have either a cap or blind flange:
Four flanged EPA ports in the stack Two connections at the HRSG inlet Two casing connections per module Casing drains (1 to 2 per module) One stack drain
6.3 Project Specific Scope
6.3.1 Desuperheater Valves
These valves consist of a desuperheater feedwater control valve plus a feedwater stop valve, which represents the ASME code break. Nooter/Eriksen provides a desuperheater with an integral or separate control valve to best fit the application. The desuperheater stop valve Is provided with an open-close motor operator. 6.3.2Steam Non-Return Valve
If two or more steam sources are feeding a common line or turbine, the Code requires an additional valve, either<~ steam non-return valve or a steam stop valve. A non-return valve effectively acts as both a stop valve and a check valve, alloWing for protection against back flow of steam into the HRSG and serves as an isolation valve at the HRSG outlet.
The steam non-return valve will be listed in the trim list if supplied.
6.3.3Feedwater Control Valves
These pneumatically actuated valves are used to regulate the flow of feedwater into the HRSG. A class V
shutoff will be provided. Cavitational trim is included as required to meet the service conditions.
6.3.4Start-Up Vent Valves
These valves consist of a gate valve followed by a globe valve vented to atmosphere. They are utilized
during start-up as a means of controlling the rate of temperature change of the HRSG. The start-up vent
valve is provided with an open-close motor operator. If specified, a modulating control valve will be
offered.
6.3.5Economizer Bypass Valve
There are two pneumatically actuated butterfly valves for controlling the amount of bypass water.
6.3.6 Deleted
6.3.7Additional Motor Operators for Remote Operation
The following valves are provided with open-close motor operators for automatic operation:
Superheater/Reheater Common Drain Valve
6.4 General Trim & Instrumentation Comments
Nooter/Eriksen's scope for all valves and instrumentation is local to the device and does not include any
conduit/wiring, junction boxes, pneumatic tubing, etc. to a common location. It has been Nooter/Eriksen's
experience that all conduit/wiring, tubing, junction boxes, etc. is best supplied by the field erection
contractor.
Newco is the primary supplier for manually operated small bore gate, globe and check valves. The use of other suppliers will require additional cost and delivery time. Specialty applications including blowoff, blowdown and F91 material may be supplied by other than Newco.
All instrument wire and cabling by Nooter/Eriksen shall be terminated local to the instrument.
7.0 Design Basis
The following summary defines the basis for Nooter/Eriksen' s HRSG design and sales price. Additional or different design conditions, if requested by Greenfield South Power, will be reviewed for their technical and commercial impact.
7.1 Contract and Specifications
7.1.1 Nooter/Eriksen's scope of supply is defined in its Proposal. 7.1.2 Conformance to the draft contract and Specification will be in accordance with any
Exceptions/Clarifications noted in the Section 12.
7.2 HRSG Performance
7.2.1 Guaranteed HRSG performance is as defined in Section 8 "Performance Guarantee'.
7.2.2 Turbine exhaust conditions are .shown in Attachment 1- HRSG Heat Balances. Nooter/Eriksen assumes that the specification covers all applicable operating conditions including maximum and minimum ambient temperature conditions, part load cases, varying fuel conditions, and power augmentation cases, etc. . .
7.2.3 The HRSG design is based on operation at pressures as shown in Attachment 1- HRSG Heat Balances. Nooter/Eriksen assumes that the cases contained therein define the highest drum operating pressure and the lowest drum operating pressure at a full load condition or otherwise adequately defines the sliding pressure operation of the HRSG(s).
7.2.4 All extraction or additional flows are shown in Attachment 1- HRSG Heat Balances.
7.2.5 The duct burner is capable of firing at the conditions shown in Attachment 1- HRSG Heat Balances .. It is assumed that the cases contained therein adequately define the operation of the duct burner including maximum firing duty at low and high ambient temperatures, firing on power augmentation, and varying fuel conditions, etc.
7.2.6 Supplementary firing will be allowed at combustion turbine full load operation only.
7.2.7 The duct burner firing will be limited so that the maximum duct burner duty is limited to 250.0 MMBtu/hr (LHV). This maximum duty will be achievable at a maximum ambient condition of 95 'F. AI higher ambients, the burner duty will be limited to Jess than this maximum level based upon a limitation on the HP Superheater #1 outlet temperature of 980 'F.
7.2.8 The duct burner firing will be limited so that the superheated steam temperature exiting Reheater #1/HP Superheater #1 does not exceed 1115/980 'F. Also, the duct burner firing will be limited to a maximum duty of 250.0 MMBtu/hr (LHV).
7.2.9 The HRSG has not been designed to operate with desuperheater failure. If the superheater design conditions are exceeded, the combustion turbine should be adjusted to bring the steam temperature within specified limits.
7 .2.1 0 Deleted
PURCHASER Contract-Mar 21, JDll Page·87 of I 08 Execution Document
7.2.11 The HRSG will be designed on the basis that the reheater will be operated wet with steam flow at all times, requiring a conditioning station be supplied by others to provide steam to the reheater coil during start-up or steam turbine bypass operation. This conditioning station takes steam from the HP superheater outlet and delivers it to the reheater inlet at normal cold reheat conditions.
7.2.12 The thermal design assumes that the site elevation is 380 feet or less above sea level.
7.2.13 The water supplied to the HRSG is deaeratedlhas less than 20 ppb 02.
7.2.14 FDA requirements will not be used for feedwater treatment.
7.2.15 The combustion turbine is capable of fulfilling the HRSG purge requirements of NFPA 85 Chapter 8, if applicable.
7 .2.16 Deleted
7.2.17 All emission level guarantees are at steady state operation. Performance guarantee tolerances are equal to the measurement uncertainty for all guarantee values including emissions and acoustics.
7.2.18 Performance testing will be done in accordance with the attached test procedure. All emissions testing should use standard EPA test methods.
7.2.19 Deleted
7.2.20 Nooter/Eriksen's standard gas flow distribution device is based on a maximum GT exhaust swirl angle range of +1-15 degrees.

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3. 5. 9. PURCHASER Contract- Mar 21, 2011 Page 41 of 108